scholarly journals Experimental and modeling study of wettability alteration through seawater injection in limestone: a case study

2020 ◽  
Vol 17 (3) ◽  
pp. 749-758
Author(s):  
Omolbanin Seiedi ◽  
Mohammad Zahedzadeh ◽  
Emad Roayaei ◽  
Morteza Aminnaji ◽  
Hossein Fazeli
Keyword(s):  
Oil Recovery ◽  
Contact Angle Measurement ◽  
Angle Measurement ◽  
Carbonate Reservoirs ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Rock Surface ◽  
Indirect Contact ◽  
Molecular Kinetic Theory ◽  
Wet Condition

AbstractWater flooding is widely applied for pressure maintenance or increasing the oil recovery of reservoirs. The heterogeneity and wettability of formation rocks strongly affect the oil recovery efficiency in carbonate reservoirs. During seawater injection in carbonate formations, the interactions between potential seawater ions and the carbonate rock at a high temperature can alter the wettability to a more water-wet condition. This paper studies the wettability of one of the Iranian carbonate reservoirs which has been under Persian Gulf seawater injection for more than 10 years. The wettability of the rock is determined by indirect contact angle measurement using Rise in Core technique. Further, the characterization of the rock surface is evaluated by molecular kinetic theory (MKT) modeling. The data obtained from experiments show that rocks are undergoing neutral wetting after the aging process. While the wettability of low permeable samples changes to be slightly water-wet, the wettability of the samples with higher permeability remains unchanged after soaking in seawater. Experimental data and MKT analysis indicate that wettability alteration of these carbonate rocks through prolonged seawater injection might be insignificant.

Effect of 2D Alpha-Zirconium Phosphate Nanosheets in Interfacial Tension Reduction and Wettability Alteration: Implications for Enhanced Oil Recovery

SPE Journal ◽  
2022 ◽  
pp. 1-13
Author(s):  
Song Qing ◽  
Hong Chen ◽  
Li-juan Han ◽  
Zhongbin Ye ◽  
Yihao Liao ◽  
...  
Keyword(s):  
Electron Microscopy ◽  
Interfacial Tension ◽  
Oil Recovery ◽  
Zirconium Phosphate ◽  
Contact Angle Measurement ◽  
Angle Measurement ◽  
Wettability Alteration ◽  
Tetrabutylammonium Hydroxide ◽  
Transmission Electron ◽  
2D Nanosheets

Summary α-Zirconium phosphate (α-ZrP) nanocrystals were synthesized by refluxing method and subsequently exfoliated into extremely thin 2D nanosheets by tetrabutylammonium hydroxide (TBAOH) solution. Dynamic light scattering, scanning electron microscopy (SEM), and transmission electron microscopy (TEM) were used to characterize the size distribution and morphology of α-ZrP nanosheets. Interfacial tension (IFT) and contact angle measurement were conducted by different concentrations of α-ZrP nanosheets solutions. The results displayed that the wettability of porous media surface was altered from oleophilic to hydrophilic and the IFT decreased with the increasing of α-ZrP nanosheets concentrations. A new method was proposed to calculate the Hamaker constant for 2D α-ZrP nanosheets. The calculated results displayed that α-ZrP nanosheets were not easy to agglomerate under experimental environment and when the interaction energy barrier increased, the transport amount of α-ZrP nanosheets also increased. Coreflooding tests were also performed with various concentrations and the oil recovery efficiency increased from 33.59 to 51.26% when α-ZrP nanosheets concentrations increased from 50 to 1,000 ppm.

scholarly journals A mechanistic investigation of low salinity water flooding coupled with ion tuning for enhanced oil recovery

RSC Advances ◽  
2020 ◽  
Vol 10 (69) ◽  
pp. 42570-42583
Author(s):  
Rohit Kumar Saw ◽  
Ajay Mandal
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Rock Surface ◽  
Calcite Dissolution ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Mechanistic Investigation ◽  
Salinity Water

The combined effects of dilution and ion tuning of seawater for enhanced oil recovery from carbonate reservoirs. Dominating mechanisms are calcite dissolution and the interplay of potential determining ions that lead to wettability alteration of rock surface.

scholarly journals Hybrid Engineered Water–Polymer Flooding in Carbonates: A Review of Mechanisms and Case Studies

2020 ◽  
Vol 10 (17) ◽  
pp. 6087
Author(s):  
Mariam Shakeel ◽  
Peyman Pourafshary ◽  
Muhammad Rehan Hashmet
Keyword(s):  
Oil Recovery ◽  
Petroleum Industry ◽  
Cost Effective ◽  
Polymer Flooding ◽  
Driving Factors ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Rock Surface ◽  
Hybrid Technique ◽  
High Salinity Water

The fast depletion of oil reserves has steered the petroleum industry towards developing novel and cost-effective enhanced oil recovery (EOR) techniques in order to get the most out of reservoirs. Engineered water–polymer flooding (EWPF) is an emerging hybrid EOR technology that uses the synergetic effects of engineered water (EW) and polymers to enhance both the microscopic and macroscopic sweep efficiencies, which mainly results from: (1) the low-salinity effect and the presence of active ions in EW, which help in detachment of carboxylic oil material from the rock surface, wettability alteration, and reduction in the residual oil saturation; (2) the favorable mobility ratio resulting from the use of a polymer; and (3) the improved thermal and salinity resistance of polymers in EW. Various underlying mechanisms have been proposed in the literature for EW EOR effects in carbonates, but the main driving factors still need to be understood properly. Both polymer flooding (PF) and EW have associated merits and demerits. However, the demerits of each can be overcome by combining the two methods, known as hybrid EWPF. This hybrid technique has been experimentally investigated for both sandstone and carbonate reservoirs by various researchers. Most of the studies have shown the synergistic benefits of the hybrid method in terms of two- to four-fold decreases in the polymer adsorption, leading to 30–50% reductions in polymer consumption, making the project economically viable for carbonates. EWPF has resulted in 20–30% extra oil recovery in various carbonate coreflood experiments compared to high-salinity water flooding. This review presents insights into the use of hybrid EWPF for carbonates, the main recovery driving factors in the hybrid process, the advantages and limitations of this method, and some areas requiring further work.

scholarly journals Interfacial Phenomena Effect on Sand Production Due to Optimized Smart Water with/without the Presence of Nanoparticles

2020 ◽  
Vol 10 (6) ◽  
pp. 6652-6668
Keyword(s):  
Oil Recovery ◽  
High Efficiency ◽  
Low Cost ◽  
Water Injection ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Rock Surface ◽  
Sand Production ◽  
Smart Water ◽  
Comparison Of The Results

Historically, smart water flooding is proved as one of the methods used to enhance oil recovery from hydrocarbon reservoirs. This method has been spread due to its low cost and ease of operation, with changing the composition and concentration of salts in the water, the smart water injection leads to more excellent compatibility with rock and fluids. However, due to a large number of sandstone reservoirs in the world and the increase of the recovery factor using this high-efficiency method, a problem occurs with the continued injection of smart water into these reservoirs a phenomenon happened in which called rock leaching. Indeed, sand production is the most common problem in these fields. Rock wettability alteration toward water wetting is considered as the main cause of sand production during the smart water injection mechanism. During this process, due to stresses on the rock surface as well as disturbance of equilibrium, the sand production in the porous media takes place. In this paper, the effect of wettability alteration of oil wetted sandstones (0.005,0.01,0.02 and 0.03 molar stearic acid in normal heptane) on sand production in the presence of smart water is fully investigated. The implementation of an effective chemical method, which is nanoparticles, have been executed to prevent sand production. By stabilizing silica nanoparticles (SiO2) at an optimum concentration of 2000 ppm in smart water (pH=8) according to the results of Zeta potential and DLS test, the effect of wettability alteration of oil wetted sandstones on sand production in the presence of smart water with nanoparticles is thoroughly reviewed. Ultimately, a comparison of the results showed that nanoparticles significantly reduced sand production.

scholarly journals Experimental investigation of chemical solutions effects on wettability alteration and interfacial tension reduction using nano-alkaline–surfactant fluid: an EOR application in carbonate reservoirs

2021 ◽  
Vol 11 (4) ◽  
pp. 1925-1941
Author(s):  
M. Sadegh Rajabi ◽  
Rasoul Moradi ◽  
Masoud Mehrizadeh
Keyword(s):  
Interfacial Tension ◽  
Crude Oil ◽  
Oil Recovery ◽  
Carbonate Reservoirs ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Ammonium Bromide ◽  
Total Production ◽  
Thin Sections ◽  
Chemical Solutions

AbstractThe wettability preference of carbonate reservoirs is neutral-wet or oil-wet as the prevailing of hydrocarbon reserves that affects approximately half of the total production of hydrocarbons of the world. Therefore, due to surface wettability of carbonate rocks the notable fraction of oil is held inside their pores in comparison with sandstones. Since shifting the wettability preference toward water-wet system is of great interest, numerous components were used for this purpose. In this experimental research, the wettability alteration of dolomite surface by interacting with a novel nano-surfactant–alkaline fluid has been investigated in order to diminish its adhesion to crude oil droplets. The solutions were prepared by homogenous mixing of nanosilica particles with cetyl trimethyl ammonium bromide and sodium carbonate, respectively, as a cationic surfactant and alkaline agent. The maximum wettability alteration from oil-wet to water system was obtained by employing a mixture of nanoparticles in association with surfactant–alkaline. Then, the fluids were employed in core-surface from detached and attached forms to compare their interfacial effects on saturated thin sections by crude oil and to measure the wettability. In addition, the interfacial tension (IFT) between solutions and crude oil was investigated and the maximum IFT reduction was obtained from nano-surfactant. Finally, all chemical solutions were flooded to the dolomite plugs separately after water flooding in order to evaluate the maximum oil recovery factor acquired by nano-surfactant.

The Application of Nanoparticles in Enhancing Oil Recovery by Wettability Alteration

2015 ◽  
Vol 1120-1121 ◽  
pp. 369-377 ◽  
Author(s):  
Jia Feng Jin ◽  
Yan Ling Wang ◽  
Fei Liu
Keyword(s):  
Crude Oil ◽  
Solid Surface ◽  
Oil Recovery ◽  
Contact Angle Measurement ◽  
Contact Angles ◽  
Angle Measurement ◽  
Solid Surfaces ◽  
Wettability Alteration ◽  
Spreading Behavior ◽  
Conventional Surfactant

Wettability is one of most important characteristics for governing the flow and distribution of reservoir fluids in the porous media,the wetting and spreading behavior of liquids on the solid surfaces changes if the wettability of solid surface is altered. Recent studies show the spreading behavior of liquids on solid surface can be significantly improved after nanofluid treatment. In order to investigate the influence of wettability alternation on enhancing oil recovery after nanofluid treatment,flushing oil experiment and contact angle measurement were conducted in the laboratory. The first experiment involved flushing crude oil with the nanofluid and conventional surfactants, respectively. In the second case, the contact angles of oil phase in nanofluid (conventional surfactant solutions)-crude oil-slide systems were measured after treating 36 hours. The results indicated that nanofluid can produce a better flushing efficiency compared with that of conventional surfactant, and the contact angles of oil phase increased from 33° to 118° after nanofluid treatment in nanofluid/crude-oil/slide system. The mechanism of enhanced oil recovery of nanofluid is mainly wettability alternation.

Effect of Microcellulose on Wettability of Reservoir Rock Surface Model

2019 ◽  
Vol 811 ◽  
pp. 55-61
Author(s):  
Mia Ledyastuti ◽  
Galuh Sukmarani
Keyword(s):  
Contact Angle ◽  
Oil Recovery ◽  
Contact Angle Measurement ◽  
Angle Measurement ◽  
Reservoir Rock ◽  
Rock Surface ◽  
Surface Model ◽  
Particle Sizes ◽  
Produce Water ◽  
The Difference

Wettability is one factor that influences the enhanced oil recovery. Water-wet surfaces are predicted increasing the oil recovery from the reservoir. Microcellulose has the potential to produce water-wet surfaces. In this experiment, two types of microcellulose were used with different particle sizes of 2.9 μm and 14 μm. Both types of microcellulose are then applied to the reservoir rock surface model, i.e the surface of bentonite which has been soaked in crude oil for one week at 60 °C. Contact angle measurement shows that there is a decrease in water-the reservoir rock surface model contact angle from ~ 90 ° to ~ 80 ° when applied microcellulose solution 0.5% w/w. The difference in microcellulose size causes a difference in contact angle of about 5° at microcellulose solution 2.5%. This shows the application of microcellulose on the reservoir rock surface model causing the surface to be more water-wet.

Wettability Alteration of Dolomite Rock Using Nanofluids for Enhanced Oil Recovery

2016 ◽  
Vol 864 ◽  
pp. 194-198 ◽  
Author(s):  
Mohd Shahrizan Moslan ◽  
Wan Rosli Wan Sulaiman ◽  
Abdul Razak Ismail ◽  
Mohd Zaidi Jaafar ◽  
Issham Ismail
Keyword(s):  
Contact Angle ◽  
Interfacial Tension ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Ion Pairs ◽  
Adsorption Rate ◽  
Wettability Alteration ◽  
Rock Surface ◽  
Wet Condition ◽  
The Impact

Wettability alteration of rock by surfactant has been considered as feasible method for recovery of oil reservoirs by modifying the wettability of rock surface from oil-wet to water-wet condition. The impact of surfactant can be enhanced by adding nanoparticles. Cationic surfactant performed well in carbonate rock by forming ion pairs between cationic head and acidic component of the crude. Meanwhile, nanoparticles will form continuous wedge film between the liquid and solid surface. In this paper, Al2O3 and ZrO2 nanoparticles were used as enhanced oil recovery (EOR) agents. The impact of these two nanoparticles on contact angle and interfacial tension was studied. Besides that, adsorption Cetyltrimethylammonium Bromide (CTAB) surfactant on rock surface was also investigated. The results show a significant change in water-oil contact angle after application of surfactant and nanoparticles. Initial water-oil contact angle for 6 dolomites demonstrate oil-wet condition. Then, the dolomites were submerged in prepared solution for 48 hours. The result shows that, dolomites 2, 5 and 6 changes drastically to more water-wet condition with contact angle 56°, 40° and 47° respectively. For surfactant adsorption, the adsorption is very fast at the beginning. The adsorption rate after 5 minutes was 50 mg/g and after 60 minutes the adsorption rate was 310 mg/g. The adsorption rate slowed down after 60 minutes and after 180 minutes the adsorption rate was 315 mg/g in which the rate of adsorption achieve equilibrium. Nanoparticles retention test and Zeta potential shows that Al2O3 is more stable than ZrO2. The results for interfacial tension (IFT) also show a significant reduction. The IFT value reduces from 8.46 mN/m to 1.65 mN/m and 1.85 mN/m after the application of Al2O3 and ZrO2 nanofluids respectively

Study on the Mechanism of Enhancing Oil Recovery by Molecular Film Displacement

2011 ◽  
Vol 236-238 ◽  
pp. 2135-2141
Author(s):  
Qi Cheng Liu ◽  
Yong Jian Liu
Keyword(s):  
Oil Recovery ◽  
Electrostatic Interaction ◽  
Ultrathin Films ◽  
Water Solution ◽  
Wettability Alteration ◽  
Nanometer Scale ◽  
Rock Surface ◽  
Capillary Imbibition ◽  
Molecular Film ◽  
Polymer Surfactant

Molecular film displacement is a new nanofilm EOR technique. A large number of experiments show that the mechanism of molecular film displacement is different from conventional chemical displacement (polymer, surfactant, alkali and ASP displacement etc). With water solution acting as transfer medium, molecules of the filming agent develop the force to form films through electrostatic interaction, with efficient molecules deposited on the negatively charged rock surface to form ultrathin films at nanometer scale. This change the properties of reservoir surface and the interaction condition with crude oil, making the oil easily be displaced as the pores swept by the injected fluid. Thus oil recovery is enhanced. The mechanism of molecular filming agent mainly includes absorption, wettability alteration, diffusion and capillary imbibition etc.

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