Chemical Enhanced Oil Recovery and Viscose Flooding into Sandstone Reservoirs Using a Natural Polymer Extracted from Sucrose‐Rich Waste by Bacterial Activity DOI Creative Commons
Iman Nowrouzi, Amir H. Mohammadi, Abbas Khaksar Manshad

et al.

Energy Technology, Journal Year: 2024, Volume and Issue: 12(8)

Published: June 20, 2024

In this research, it was attempted to describe in vitro the efficiency of a natural polymer synthesized from sugarcane waste by bacteria for application enhanced crude oil recovery. Necessary experiments were carried out with main targets extraction and description its effectiveness It is shown that concentrations 1, 2, 5, 8 wt%, viscosity equal 26.08, 76.51, 100.94, 168.36 mPa s. A shear‐thinning flow behavior observed at initial shear rates. The sandstone wettability alteration through contact angles wt% are 85.93°, 72.19°, 76.51°, 71.09°, respectively. Based on salinity compatibility, work up 90 000 ppm based tests, 120 ppm. Regarding performance solution against temperature, shows an acceptable increasing highest temperature 75 °C. water cut reaches minimum 8%, then increases. By injecting 3.3 Pore volum (PV), recovery 81.4%. polymeric slug injection program, factor 74.8%.Similarly, starts decrease after polymer, finally, 0.9 PV including 0.5 0.4 water, during experiment, i.e., 22%.

Language: Английский

Synergistic Effects of Nonionic Surfactant and Organic Alkali for Enhanced Oil Recovery: Optimizing Interfacial Tension Reduction, Emulsion Stability, and Corrosion Control under Optimal Salinity Conditions DOI

Rajib Chakraborty,

Lavisha Jangid,

Ramendra Pandey

et al.

Energy & Fuels, Journal Year: 2025, Volume and Issue: unknown

Published: Feb. 7, 2025

Language: Английский

Citations

0
Application of Biosynthesized Nanoparticles in Chemical Enhanced Oil Recovery: Main Mechanisms, Recent Advances, Challenges, and Opportunities DOI Creative Commons

Godfrey Osemudiamhen Eseigbe,

Sunday Sunday Ikiensikimama

Petroleum Research, Journal Year: 2025, Volume and Issue: unknown

Published: April 1, 2025

Language: Английский

Citations

0
A non‐ionic green surfactant extracted from the Anabasis setifera plant for improving bulk properties of CO2‐foam in the process of enhanced oil recovery from carbonate reservoirs DOI Creative Commons
Iman Nowrouzi, Amir H. Mohammadi, Abbas Khaksar Manshad

et al.

The Canadian Journal of Chemical Engineering, Journal Year: 2024, Volume and Issue: unknown

Published: July 11, 2024

Abstract Foam, as a gas‐in‐liquid colloid, has higher appearance viscosity than the one of both gas and liquid that form it. Adjusting mobility ratio injected fluid–oil system increasing diffusion in foam injection process increase oil production. With these properties, an fluid fractured reservoirs major effect on production from matrixes prevents premature fluid. Surfactants are common foaming agents water. Saponins known plant‐derived surfactants for forming stable foam. This feature, along with its cheap price availability, can make them candidates enhanced recovery (EOR) by method. However, utilization CO 2 gaseous phase introduces additional machanisms to operations. In this assessment, non‐ionic green surfactant derived Anabasis setifera plant was used agent, while served phase. A series surface tension tests environment were performed determine optimal concentration surfactant. Foaming designed generator. The produced ‐foam then into carbonate plug six (with horizontal two vertical fractures). Based results, water–CO reduced 20.549 mN/m. optimum salinity based stability 10,000 ppm. half‐life determined be 40 min. Also, characterization showed foamability favourable so secondary flooding, more 66% achieved plug.

Language: Английский

Citations

3
Benchmarking the potential of a resistant green hydrocolloid for chemical enhanced oil recovery from sandstone reservoirs DOI Creative Commons
Iman Nowrouzi, Amir H. Mohammadi, Abbas Khaksar Manshad

et al.

The Canadian Journal of Chemical Engineering, Journal Year: 2024, Volume and Issue: unknown

Published: July 11, 2024

Abstract Polymer injection into oil reservoirs stands as a primary technique for enhanced recovery (EOR), employing either natural or synthetic polymers that dissolve in water. Proper performance salinity and reservoir temperature creates limitation to replace material with common chemicals this has led researchers try identify new application. Continuing the efforts overcoming challenge, research introduces examines high‐performance polymer extracted from garden cress seeds Several experiments were planned executed based on existing EOR standards literature. Comprehensive analyses viscosity measurements performed behaviour of solutions effects concentration, shear rate, salinity, temperature. Essential tests such wettability adsorption also done by contact angle measurement flooding sandstone plug, respectively. The produced was able effectively maintain viscosification properties at temperatures up 95°C. Similarly, increasing 140,000 ppm did not affect its efficiency value remained useful range. mature 35°C after 30 h concentrations 200, 400, 600, 800, 1000, 1200 8.61, 18.59, 31.27, 65.41, 95.38, 149.75 mPa, At 1000 35, 55, 75, 95°C, 90.57, 86.73, 84.72 mPa · s, ppm, altered intermediate‐wet, while water‐wet. caused an increase equal 18.6%. water cut increased little delay initial volumes high rate reached maximum. Then 0.3 PV polymer, there sharp continuous drop until reaching 35% production fluid volume.

Language: Английский

Citations

3
Chemical enhanced oil recovery from shale‐rich tight carbonate reservoirs using 2‐butoxyethanol as a mutual solvent and diluted seawater DOI Creative Commons
Iman Nowrouzi, Amir H. Mohammadi, Abbas Khaksar Manshad

et al.

The Canadian Journal of Chemical Engineering, Journal Year: 2024, Volume and Issue: unknown

Published: Oct. 9, 2024

Abstract Oil production from tight reservoirs due to their very low permeability and high capillary pressure requires complex operations materials, so that hydraulic fracturing in these is recommended before any chemical injection. This operation turns the reservoir into a fractured one can produce more oil by activating imbibition mechanism. The interfacial tension (IFT) of water rock wettability as key parameters overproduction this type affect In study, potential 2‐butoxyethanol mutual solvent for enhanced recovery (EOR) was investigated with focus on under through performing experiments calculations IFT, swelling, contact angle, production. analysis results shows mechanisms IFT reduction, alteration, which all directly imbibition, reached desired values using appropriate concentration along dilution seawater. lowest angle at 0.03 M 5000 ppm salinity 90°C temperature were 1.315 mN/m 71.57°, respectively. These are much lower compared obtained similar additives, while solvents, unlike 2‐butoxyethanol, effective higher volume ratios. swelling increased about 14% its mass transfer between phases interface. Finally, factors 42% 59% achieved one‐ multi‐dimensional spontaneous (ODSI MDSI),

Language: Английский

Citations

0
Chemical Enhanced Oil Recovery and Viscose Flooding into Sandstone Reservoirs Using a Natural Polymer Extracted from Sucrose‐Rich Waste by Bacterial Activity DOI Creative Commons
Iman Nowrouzi, Amir H. Mohammadi, Abbas Khaksar Manshad

et al.

Energy Technology, Journal Year: 2024, Volume and Issue: 12(8)

Published: June 20, 2024

In this research, it was attempted to describe in vitro the efficiency of a natural polymer synthesized from sugarcane waste by bacteria for application enhanced crude oil recovery. Necessary experiments were carried out with main targets extraction and description its effectiveness It is shown that concentrations 1, 2, 5, 8 wt%, viscosity equal 26.08, 76.51, 100.94, 168.36 mPa s. A shear‐thinning flow behavior observed at initial shear rates. The sandstone wettability alteration through contact angles wt% are 85.93°, 72.19°, 76.51°, 71.09°, respectively. Based on salinity compatibility, work up 90 000 ppm based tests, 120 ppm. Regarding performance solution against temperature, shows an acceptable increasing highest temperature 75 °C. water cut reaches minimum 8%, then increases. By injecting 3.3 Pore volum (PV), recovery 81.4%. polymeric slug injection program, factor 74.8%.Similarly, starts decrease after polymer, finally, 0.9 PV including 0.5 0.4 water, during experiment, i.e., 22%.

Language: Английский

Citations

0