Experimental study of high-temperature CO2 foam flooding after hot-water injection in developing heavy oil reservoirs
| Autor: | Pengcheng Liu, Lanxiang Shi, Lei Li, Daode Hua, Peng Liu |
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| Rok vydání: | 2020 |
| Předmět: |
Materials science
Petroleum engineering Water injection (oil production) Polyacrylamide 02 engineering and technology 010502 geochemistry & geophysics Geotechnical Engineering and Engineering Geology 01 natural sciences Oil displacement chemistry.chemical_compound Permeability (earth sciences) Fuel Technology 020401 chemical engineering chemistry Water channel Pulmonary surfactant Low permeability Thermal stability 0204 chemical engineering 0105 earth and related environmental sciences |
| Zdroj: | Journal of Petroleum Science and Engineering. 185:106597 |
| ISSN: | 0920-4105 |
| DOI: | 10.1016/j.petrol.2019.106597 |
| Popis: | Hot water flooding is one of the main strategies employed in the recovery of heavy oil. However, the low viscosity of the injected hot water readily generates the formation of water channels in oil bearing formations with high permeability, resulting in relatively low oil recovery. This study addresses this issue by experimentally investigating the application of a CO2 foam injection process as a secondary strategy after hot water injection. Six surfactants were evaluated for foam generation at temperatures in the range of 57–200 °C in a series of screening tests, including static foam tests, thermal stability testing, and resistance factor evaluation. The optimum surfactant was accordingly selected for application in the CO2 foam injection process. The addition of 0.04 wt% anionic polyacrylamide (HPAM) as a stabilizer in the selected surfactant produced a more stable foam appropriate for use at a temperature of 80 °C or less. Oil displacement experiments were conducted using both a high permeability sand pack and a low permeability sand pack simultaneously to investigate water channel creation during hot water injection and the channel blockage resulting from the injected foam along with the corresponding oil recovery enhancement. The experimental results indicate that hot water in the hot water injection process flows readily through the high permeability sand pack and reduces the oil viscosity, which results in an increased degree of water channeling of the high-permeability sand pack. The high-temperature CO2 foam generated under optimum conditions using the selected surfactant effectively blocks the water channeling created during the preceding hot water injection process and significantly increases the oil displacement efficiencies of both the low- and high-permeability sand packs. The results of this study demonstrate that the secondary injection of CO2 foam following hot water injection represents a promising heavy oil recovery strategy for developing heavy oil reservoirs. |
| Databáze: | OpenAIRE |
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