Laboratory Study of CO2 Foam Flooding in High Temperature, High Salinity Carbonate Reservoirs Using Co-injection Technique
| Autor: | Muhammad Rehan Hashmet, Evans Anto-Darkwah, Waleed Alameri, Ali M. AlSumaiti |
|---|---|
| Rok vydání: | 2018 |
| Předmět: |
Materials science
Shear thinning 020209 energy General Chemical Engineering Energy Engineering and Power Technology 02 engineering and technology Apparent viscosity Volumetric flow rate Co injection Salinity Permeability (earth sciences) chemistry.chemical_compound Fuel Technology 020401 chemical engineering Pulmonary surfactant chemistry 0202 electrical engineering electronic engineering information engineering Carbonate lipids (amino acids peptides and proteins) cardiovascular diseases 0204 chemical engineering Composite material |
| Zdroj: | Energy & Fuels. 32:1416-1422 |
| ISSN: | 1520-5029 0887-0624 |
| Popis: | In this research, an ethoxylated amine surfactant is co-injected with CO2 in a series of coreflooding experiments at typical Middle Eastern reservoir conditions of high temperature, high salinity, and in situ foam is generated to reduce gas mobility in the absence of oil. The effects of reservoir permeability, injection rates, and foam quality on mobility reduction factor (MRF) and apparent viscosity of foam are discussed. In the absence of oil, an optimum foam quality of 80% is obtained using 1 wt % of surfactant solution. Shear thinning foams with viscosities ranging between 0.9 and 2.4 cP were formed at all velocities tested in this study. MRFs of 50 and 70 were obtained, respectively, in 70 and 240 mD cores at 80% foam quality, confirming that foam strength increases with increasing rock permeability. After determination of optimum foam quality and flow rate, a final coreflooding experiment was conducted in the presence of oil to quantify the effect of oil presence on foam generation and to observe th... |
| Databáze: | OpenAIRE |
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