Quantitative evaluation of factors affecting foamy oil recovery in the development of heavy hydrocarbon reservoirs

2016 ◽  
Vol 41 (35) ◽  
pp. 15624-15631 ◽  
Author(s):  
Pengcheng Liu ◽  
Wenhui Li ◽  
Mingqiang Hao ◽  
Yongbin Wu ◽  
Xiuluan Li
Keyword(s):  
Quantitative Evaluation ◽  
Oil Recovery ◽  
Hydrocarbon Reservoirs ◽  
Factors Affecting ◽  
Heavy Hydrocarbon ◽  
Foamy Oil

scholarly journals Experimental Study on Factors Affecting the Performance of Foamy Oil Recovery

Energies ◽  
2019 ◽  
Vol 12 (4) ◽  
pp. 637 ◽  
Author(s):  
Weifeng Lv ◽  
Dongxing Du ◽  
Jiru Yang ◽  
Ninghong Jia ◽  
Tong Li ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Recovery Rate ◽  
Flow Characteristics ◽  
Production Model ◽  
Inlet Section ◽  
Gas Oil ◽  
Obvious Effect ◽  
Factors Affecting ◽  
Foamy Oil ◽  
Depletion Rate

The flow characteristics of dissolved gas driven processes in some heavy oil reservoirs, such as low gas–oil ratio and higher oil recovery rate than expected, are quite different from conventional oil production processes. Foamy oil is considered one of the main reasons behind such a production phenomenon. In this paper, the factors affecting the performance of foamy oil recovery were experimentally investigated in a sandpack medium with the assistance of computed tomography (CT) technology to help further the understanding of the mechanism. Five different experiments were applied and the results showed that (1) the linear pressure drop production model had a similar oil recovery to that of the step-down mode; (2) increasing the depletion rate could be more favorable to the oil recovery rate; (3) under a constant gas–oil ratio, raising the temperature had little impact on oil recovery, but showed obvious impact on the production curve; and (4) with higher permeability, there were more residual oil at the end of the displacement process. Lastly, a dry gas huff and puff experiment was conducted and the decreased oil saturation was observed in the inlet section, while no obvious effect was remarked in the outlet region of the medium.

scholarly journals The Empirical and Theoretical Miscible Characterization Method in Gas-Enhanced Oil Recovery

Geofluids ◽  
2018 ◽  
Vol 2018 ◽  
pp. 1-9
Author(s):  
Wang Chengjun ◽  
Li Xiaorui
Keyword(s):  
Oil Recovery ◽  
Research Result ◽  
Empirical Method ◽  
Reservoir Engineering ◽  
Forecasting Accuracy ◽  
Factors Affecting ◽  
Development Scheme ◽  
Gas Flooding ◽  
New Ideas

The determination of miscible characteristic is one of the key technologies for enhancing oil recovery of gas flooding. If the miscible characteristic at each development period of gas flooding can be known in real time, it will be helpful to guide gas flooding development scheme. The minimum miscible pressure (MMP) is mostly used to describe miscible characteristic. Currently, the MMP forecasting methods can be classified into two categories—the empirical method and theoretical calculation method. In this paper, the main controlling factors affecting MMP are analyzed combined with reservoir engineering method, phase equilibrium theory, reservoir numerical simulation technology, and so on. Based on this, new empirical and theoretical MMP forecasting model was built. Meanwhile, new ideas for improving forecasting accuracy through modifying miscible criterion were proposed. The calculation accuracies of the two MMP forecasting models can be improved to over 90% that is more accurate and adapted than other methods. This research result can supply new ideas for gas flooding MMP forecasting.

Experimental Analysis of the Effects of Varying Temperature and Viscosities on Foamy Oil Production

2021 ◽  
Author(s):  
Jasmine Shivani Medina ◽  
Iomi Dhanielle Medina ◽  
Gao Zhang
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Elevated Temperatures ◽  
Oil Production ◽  
Oil Reservoirs ◽  
Oil Viscosity ◽  
Gas Recovery ◽  
Foamy Oil ◽  
Heavy Oil Reservoirs ◽  
Pressure Depletion

Abstract The phenomenon of higher than expected production rates and recovery factors in heavy oil reservoirs captured the term "foamy oil," by researchers. This is mainly due to the bubble filled chocolate mousse appearance found at wellheads where this phenomenon occurs. Foamy oil flow is barely understood up to this day. Understanding why this unusual occurrence exists can aid in the transfer of principles to low recovery heavy oil reservoirs globally. This study focused mainly on how varying the viscosity and temperature via pressure depletion lab tests affected the performance of foamy oil production. Six different lab-scaled experiments were conducted, four with varying temperatures and two with varying viscosities. All experiments were conducted using lab-scaled sand pack pressure depletion tests with the same initial gas oil ratio (GOR). The first series of experiments with varying temperatures showed that the oil recovery was inversely proportional to elevated temperatures, however there was a directly proportional relationship between gas recovery and elevation in temperature. A unique observation was also made, during late-stage production, foamy oil recovery reappeared with temperatures in the 45-55°C range. With respect to the viscosities, a non-linear relationship existed, however there was an optimal region in which the live-oil viscosity and foamy oil production seem to be harmonious.

Foamy Oil Formation by Gas Injection and the Effect on Heavy Oil Recovery

2015 ◽  
Vol 33 (7) ◽  
pp. 846-854
Author(s):  
X. Sun ◽  
Y. Zhang ◽  
C. Zhao ◽  
W. Li ◽  
X. Li
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Gas Injection ◽  
Heavy Oil Recovery ◽  
Foamy Oil ◽  
Oil Formation

Numerical Simulation of Foamy Oil Stability Using Natural Gas Huff and Puff for Ultra-Deep Heavy Oil Reservoir

2013 ◽  
Vol 318 ◽  
pp. 405-409 ◽  
Author(s):  
Ju Hua Li ◽  
Rong Bao ◽  
Bin Qin ◽  
Tao Jiang
Keyword(s):  
Numerical Simulation ◽  
Natural Gas ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Mobility Ratio ◽  
Permeability Ratio ◽  
Foamy Oil ◽  
Horizontal Permeability ◽  
The Stability ◽  
Dispersion Number

The nature of injected gas dispersion in oil distinguishes foamy oil behavior from conventional heavy oil behavior. Unlike normal two-phase flow, it involves flow of dispersed gas bubbles with pseudo single phase. This paper presents the results of a numerical simulation study of the stability of foamy oil created by liberation of dissolved gas during natural gas huff and puff process. Through the history matching of labs test conducted by three series of various core tubes in numerical simulation, foamy oil impactions on recovery were discussed based on vertical heterogeneous model. The effects on the stability of foamy oil flow behavior were investigated by mobility ratio, viscous to gravity ratio, layer permeability contrast, vertical to horizontal permeability ratio and the transverse dispersion number in the paper. The results show that foamy oil stability increases with higher oil viscosity, higher injection gas density. The oil recovery decrease with the mobility ratio and the layer permeability contrast, while the oil recovery increase with the vertical to horizontal permeability ratio. This work demonstrates that the transverse dispersion number should be used to assess vertical or microscopic sweep efficiency. The study indicates that foamy oil in porous media during production is unstable, but it will be huge potentials to apply natural gas huff and puff for ultra-deep heavy oil reservoirs.

Feasibility study of enhanced foamy oil recovery of the Orinoco Belt using natural gas

2014 ◽  
Vol 122 ◽  
pp. 94-107 ◽  
Author(s):  
Xiaofei Sun ◽  
Yanyu Zhang ◽  
Guoliang Cui ◽  
Xuewei Duan ◽  
Chunyan Zhao
Keyword(s):  
Natural Gas ◽  
Feasibility Study ◽  
Oil Recovery ◽  
Foamy Oil
Sign in / Sign up

Export Citation Format

Share Document