scholarly journals Laboratory Testing of Novel Polyfraction Nanoemulsion for EOR Processes in Carbonate Formations

Energies ◽  
2020 ◽  
Vol 13 (16) ◽  
pp. 4175
Author(s):  
Piotr Kasza ◽  
Marek Czupski ◽  
Klaudia Wilk ◽  
Mateusz Masłowski ◽  
Rafał Moska ◽  
...  
Keyword(s):  
High Pressure ◽  
Oil Recovery ◽  
Carbonate Rocks ◽  
High Efficiency ◽  
Core Flooding ◽  
Reservoir Water ◽  
High Pressure High Temperature ◽  
Eor Processes ◽  
Carbonate Formations ◽  
Physical Phenomena

Nanoemulsions and polymers are widely used for increasing the efficiency of enhanced oil recovery (EOR) processes. The application of both these additives enables the synergistic use of several physical phenomena that are crucial to the process. One of the methods used for assessing these processes is laboratory core flooding tests using natural cores. In various experiments, carbonate rocks are subjected to oil displacement under high pressure and temperature. Polymer solutions and a newly developed polyfraction nanoemulsion are tested. The test results confirm the usefulness of these products for EOR processes and demonstrate their stability under high pressure, high temperature, and in the presence of H2S. Under these conditions the polymers maintain high efficiency in displacing crude oil from carbonate rocks, while the tested nanoemulsion improves the wettability of carbonate rocks and reduces interfacial tension, factors which increase the efficiency of oil displacement.The best result in the laboratory EOR simulation was obtained for polymer and nanoemulsion concentrations in dilute reservoir water of 0.05% and 1%, respectively. In this case, the measured oil recovery was 37.5% higher than that obtained when using water without additives.

Optimization of Smart Water Chemical Composition for Carbonate Rocks Through Comparison of Active Cations Performance

2017 ◽  
Vol 139 (6) ◽  
Author(s):  
Malek Jalilian ◽  
Peyman Pourafshary ◽  
Behnam Sedaee Sola ◽  
Mosayyeb Kamari
Keyword(s):  
Chemical Composition ◽  
Oil Recovery ◽  
Carbonate Rocks ◽  
Low Cost ◽  
Recovery Phase ◽  
Ion Concentration ◽  
Water Flooding ◽  
Core Flooding ◽  
Smart Water ◽  
The Impact

Designing smart water (SW) by optimizing the chemical composition of injected brine is a promising low-cost technique that has been developed for both sandstone and carbonate reservoirs for several decades. In this study, the impact of SW flooding during tertiary oil recovery phase was investigated by core flooding analysis of pure limestone carbonate rocks. Increasing the sulfate ion concentration by using CaSO4 and MgSO4 of NaCl concentration and finally reducing the total salinity were the main manipulations performed to optimize SW. The main objective of this research is to compare active cations including Ca2+ and Mg2+ in the presence of sulfate ions (SO42−) with regard to their efficiency in the enhancement of oil production during SW flooding of carbonate cores. The results revealed a 14.5% increase in the recovery factor by CaSO4 proving its greater effectiveness compared to MgSO4, which led to an 11.5% production enhancement. It was also realized that low-salinity water flooding (LSWF) did not lead to a significant positive effect as it contributed less than 2% in the tertiary stage.

scholarly journals Wettability alteration analysis of smart water/novel functionalized nanocomposites for enhanced oil recovery

2020 ◽  
Vol 17 (5) ◽  
pp. 1318-1328
Author(s):  
Sara Habibi ◽  
Arezou Jafari ◽  
Zahra Fakhroueian
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Ionic Composition ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Core Flooding ◽  
Sulfate Ions ◽  
Smart Water ◽  
Eor Processes ◽  
Co Precipitation

Abstract Smart water flooding, as a popular method to change the wettability of carbonate rocks, is one of the interesting and challenging issues in reservoir engineering. In addition, the recent studies show that nanoparticles have a great potential for application in EOR processes. However, little research has been conducted on the use of smart water with nanoparticles in enhanced oil recovery. In this study, stability, contact angle and IFT measurements and multi-step core flooding tests were designed to investigate the effect of the ionic composition of smart water containing SO42− and Ca2+ ions in the presence of nanofluid on EOR processes. The amine/organosiloxane@Al2O3/SiO2 (AOAS) nanocomposite previously synthesized using co-precipitation-hydrothermal method has been used here. However, for the first time the application of this nanocomposite along with smart water has been studied in this research. Results show that by increasing the concentrations of calcium and sulfate ions in smart water, oil recovery is improved by 9% and 10%, respectively, compared to seawater. In addition, the use of smart water and nanofluids simultaneously is very effective on increasing oil recovery. Finally, the best performance was observed in smart water containing two times of sulfate ions concentration (SW2S) with nanofluids, showing increased efficiency of about 7.5%.

Evaluation and Application of Endogenous Microorganism Activator in Reservoir after Chemical Flooding

2014 ◽  
Vol 1051 ◽  
pp. 404-409
Author(s):  
Jian Jun Le ◽  
Ji Yuan Zhang ◽  
Lu Lu Bai ◽  
Rui Wang ◽  
Zhao Wei Hou ◽  
...  
Keyword(s):  
Electron Microscopy ◽  
High Pressure ◽  
Oil Recovery ◽  
Physical Simulation ◽  
Chemical Flooding ◽  
Core Flooding ◽  
Simulation Experiments ◽  
The Core ◽  
Enhance Oil Recovery ◽  
Growth And Reproduction

To further enhance oil recovery in reservoir after chemical flooding, an efficient activator formulation for promoting metabolism of endogenous microorganism was researched. Changes in community structure, growth and metabolites of endogenous microorganism were analyzed by methods of aerogenic experiments, physical simulation experiments, electron microscopy scanning (SEM), T-RFLP and Pyrophosphate sequencing. To evaluate whether endogenous microorganism activator screened in laboratory could activate endogenous microorganisms and enhance oil recovery in reservoirs after polymer flooding. The flooding effect and mechanism were studied, and this activator was used in a testing well group in Daqing oilfield. The results of the aerogenic experiments showed that the activator could activate the endogenous microorganisms in the injected water and make them produce a lot of biogas. The pressurized gas reached 2MPa after 60d static culture of activator in a high pressure vessel. The results showed that the activator could activate the endogenous microorganisms in the injected sewage and make them have a lot of growth and reproduction in the core and physical simulation of natural core flooding experiment. In the field test,the incremental oil production was 5957 t while the water content declined by 2.2% after injecting the activator, which provides an effective way to further enhance oil recovery in reservoir after chemical flooding.

scholarly journals The Control of Apparent Wettability on the Efficiency of Surfactant Flooding in Tight Carbonate Rocks

Processes ◽  
2019 ◽  
Vol 7 (10) ◽  
pp. 684 ◽  
Author(s):  
Harris Sajjad Rabbani ◽  
Yossra Osman ◽  
Ibrahim Almaghrabi ◽  
Mohammad Azizur Rahman ◽  
Thomas Seers
Keyword(s):  
Oil Recovery ◽  
Carbonate Rocks ◽  
Critical Role ◽  
Pore Scale ◽  
Surfactant Flooding ◽  
Core Flooding ◽  
Field Development ◽  
Three Samples ◽  
Tight Carbonate

In this research, a state-of-the-art experimental core flooding setup is used to assess the efficiency of surfactant flooding as an enhanced oil recovery (EOR) technique in tight carbonate rocks. Specifically, we investigate the role of apparent wettability in governing the effectiveness of surfactant flooding. A series of flooding experiments with well-defined boundary conditions were performed on the low permeability core plug samples of Indiana Limestone (calcite-cemented carbonate grainstones). Experiments were conducted on three samples exhibiting differing apparent wetting characteristics: strongly oil-wet, moderately oil-wet and weakly oil-wet. Initially, the oil-saturated core samples were flooded with brine until the residual oil saturation was achieved, with surfactant flooding performed as a tertiary recovery technique. Interestingly, our experimental results reveal that the efficiency of surfactant flooding increases with the degree of oil-wetness of the tight carbonate rocks. The strongly oil-wet core showed the highest recovery, while the weakly oil-wet core manifested the least additional oil recovery associated with surfactant flooding. Moreover, we provided a pore-scale argument that explains the macroscopic role of surfactant flooding in tight carbonate rocks. We hypothesized that at the pore-scale the presence of thin film plays a critical role in controlling the effectiveness of surfactant flooding in the strongly oil-wet tight carbonate rocks. Overall, we believe that our macroscopic study provides novel insight into the dynamics of surfactant flooding in tight carbonate reservoirs and can aid in optimizing the field development plans for oil recovery.

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