Retrieval of Solvent Injected During Heavy-Oil Recovery from Water - and Oil-Wet Reservoirs: Pore Scale Analysis at Variable Temperature Conditions

2016 ◽  
Author(s):  
Jingwen Cui ◽  
Tayfun Babadagli
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Variable Temperature ◽  
Scale Analysis ◽  
Heavy Oil Recovery ◽  
Pore Scale ◽  
Temperature Conditions

2-D Pore-Scale Experimental Investigations of Asphaltene Deposition and Heavy Oil Recovery by CO2 Flooding

2018 ◽  
Vol 32 (3) ◽  
pp. 3194-3201 ◽  
Author(s):  
Zhiyong Song ◽  
Weiyao Zhu ◽  
Xue Wang ◽  
Shengxue Guo
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Experimental Investigations ◽  
Heavy Oil Recovery ◽  
Co2 Flooding ◽  
Pore Scale ◽  
Asphaltene Deposition

Pore-scale description of surfactant-enhanced waterflooding for heavy oil recovery

2012 ◽  
Vol 92-93 ◽  
pp. 89-101 ◽  
Author(s):  
Benyamin Yadali Jamaloei ◽  
Riyaz Kharrat
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Heavy Oil Recovery ◽  
Pore Scale

Field-Scale Analysis of Heavy-Oil Recovery by Electrical Heating

2010 ◽  
Vol 13 (01) ◽  
pp. 131-142 ◽  
Author(s):  
Berna Hascakir ◽  
Tayfun Babadagli ◽  
Serhat Akin
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Electrical Heating ◽  
Scale Analysis ◽  
Heavy Oil Recovery ◽  
Field Scale

Potential of a new water-soluble agent for enhancing heavy oil recovery: A pore-scale investigation

2021 ◽  
pp. 109646
Author(s):  
Mingkun Zhai ◽  
Qingjun Du ◽  
Yueliang liu ◽  
Guanghuan Wu ◽  
Jianfang Sun ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Water Soluble ◽  
Heavy Oil Recovery ◽  
Pore Scale

New Insight on Carbonate-Heavy-Oil Recovery: Pore-Scale Mechanisms of Post-Solvent Carbon Dioxide Foam/Polymer-Enhanced-Foam Flooding

SPE Journal ◽  
2016 ◽  
Vol 21 (05) ◽  
pp. 1655-1668 ◽  
Author(s):  
Ali Telmadarreie ◽  
Japan J. Trivedi
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Carbonate Reservoirs ◽  
Heavy Oil Recovery ◽  
Pore Scale ◽  
Sweep Efficiency ◽  
Solvent Injection ◽  
Co2 Foam ◽  
The Matrix ◽  
Heavy Crude

Summary Carbonate reservoirs, deposited in the Western Canadian Sedimentary Basin (WCSB), hold significant reserves of heavy crude oil that can be recovered by nonthermal processes. Solvent, gas, water, and water-alternating-gas (WAG) injections are the main methods for carbonate-heavy-oil recovery in the WCSB. Because of the fractured nature of carbonate formations, many advantages of these production methods are usually in contrast with their low recovery factor. Alternative processes are therefore needed to increase oil-sweep efficiency from carbonate reservoirs. Foam/polymer-enhanced-foam (PEF) injection has gained interest in conventional heavy-oil recovery in recent times. However, the oil-recovery process by foam, especially PEF, in conjunction with solvent injection is less understood in fractured heavy-oil-carbonate reservoirs. The challenge is to understand how the combination of surfactant, gas, and polymer allows us to better access the matrix and efficiently sweep the oil. This study introduces a new approach to access the unrecovered heavy oil in fractured-carbonate reservoirs. Carbon dioxide (CO2) foam and CO2 PEF were used to decrease oil saturation after solvent injection, and their performance was compared with gas injection. A specially designed fractured micromodel was used to visualize the pore-scale phenomena during CO2-foam/PEF injection. In addition, the static bulk performances of CO2 foam/PEF were analyzed in the presence of heavy crude oil. A high-definition camera was used to capture high-quality images. The results showed that in both static and dynamic studies the PEF had high stability. Unlike CO2 PEF, CO2 foam lamella broke much faster and resulted in the collapse of the foam during heavy-oil recovery after solvent flooding. It appeared that foam played a greater role than just gas-mobility control. Foam showed outstanding improvement in heavy-oil recovery over gas injection. The presence of foam bubbles was the main reason to improve heavy-oil-sweep efficiency in heterogeneous porous media. When the foam bubbles advanced through pore throats, the local capillary number increased enough to displace the emulsified oil. PEF bubbles generated an additional force to divert surfactant/polymer into the matrix. Overall, CO2 foam and PEF remarkably increased heavy-oil recovery after solvent injection into the fractured reservoir.

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