Gelled Emulsions of CO2-Water-Nanoparticles

Otaibi, Fawaz Mohammed Al; Kokal, Sunil; Yun, Chang Soo; Al-Qahtani, Jassi; Alabdulwahab, Amin

doi:10.2118/166072-ms

Cited by 12 publications

(5 citation statements)

References 21 publications

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“…The harsh conditions such as reservoir temperature, high salinity, and surfactant adsorption to the rock may result in weak foam generation and therefore poor sweep efficiency. − The use of nanoparticles may offer an alternative to surfactant to stabilize foam at harsh reservoir conditions. The nanoparticles can strongly adsorb at the interface and stabilize foams at high temepature and salinity. − Also, the synergistic effect of surfactant and nanoparticles or the modification of the surface of solid nanoparticles through physiochemical interactions with surfactants may enhance foam stability and generate stronger foams than surfactants. Several studies reported the ability of mixtures of surfactant and nanoparticles to enhance the foam stability. − Zhang et al (2008) used a mixture of laponite particles and surfactant, tetraethylene glycol monododecyl ether, and found an enhancement in foam stability under certain conditions .…”

Section: Introductionmentioning

confidence: 99%

Enhancing the Stability of Foam by the Use of Nanoparticles

2017

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Foam generation is one of the most promising techniques to overcome gas mobility challenges and improve the sweep efficiency of reservoir fluids. The synergistic effect of surfactant and nanoparticles can help produce a stronger and more stable foam in reservoir porous media. The objective of this work is to assess the ability of anionic surfactant and a mixture of the surfactant and nanoparticles to produce foam for gas mobility control and the enhancement of oil recovery. Static, dynamic, and core flood tests were conducted to evaluate foam strength. Static foam tests in the presence of crude oil showed a clear trend on foam behavior when solid nanoparticles were added to surfactant. As the concentration of nanoparticles increases, the foam half-life increases, too. Foamability tests in Bentheimer sandstone showed better foam generation and stabilization when nanoparticles were used. The addition of nanoaprticles to surfactant solutions resulted in higher pressure drop and, therefore, higher reduction of gas mobility compared to surfactant. The rise in temperature from 25 to 50 °C reduces the measured pressure drop across the core samples in the absence and presence of nanoparticles, which can be attributed to the reduction in foam stability and strength. Both surfactant and a mixture of surfactant and nanoparticles were able to enhance oil recovery. The surfactant was able to bring the oil recovery to 41.45% of the original oil in place (OOIP). In contrast, the presence of nanoparticles resulted in higher oil recovery, 49.05%, of the OOIP.

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Section: Introductionmentioning

confidence: 99%

Enhancing the Stability of Foam by the Use of Nanoparticles

2017

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“…This defeats the sole reason of HCl usage since matrix acidizing cost increases as carbonic acid is much expensive compared to HCl for equivalent amount of rock dissolved (Chang et al 2008;Raj and Pal 2014). Modified acid is investigated on improving the efficiency of matrix acidizing (Zakaria and Nasr-El-Din 2016;Al Otaibi et al 2013;Carpenter 2014). The study does not comprehend the issue of CO 2 gas release from the reaction between HCl acid and carbonate rock.…”

Section: Carbonate Reservoirs and Matrix Acidizingmentioning

confidence: 99%

Experimental study of nanoparticles as catalyst in enhancing matrix acidizing for carbonate reservoir

Selvaraj

Maulianda

Wee

et al. 2019

J Petrol Explor Prod Technol

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Hydrochloric (HCl) acid is the most common stimulating fluid used in acidizing job due to its strong acidic property and low cost to create or enlarge existing wormhole within the reservoir. However, the HCl acid has rapid reaction with carbonate reservoir, and it is causing surface dissolution of the rock and lowering the penetration into the formation. Recent studies have shown the addition of nickel nanoparticles as catalyst to handle the problems in HCl acidizing. The nanoparticles are high-performance catalyst due to their high ratio of surface area to volume. The proposed method in this research is to mix the nanoparticles with the carbonate formation prior to the acid injection into the formation. The efficiency of the nanoparticles as catalyst depends on the thermodynamics property, which is surface energy of the materials used. The surface energy reduces as the size of particles become smaller. However, the effect of surface energy become insignificant on nanoparticles due to the small particles sizes, and the surface energy is based on the individual energy of the particles. Therefore, this research investigates the efficiency of silica, aluminum oxide, and zinc oxide besides nickel nanoparticles based on their thermodynamics property in accelerating the conversion of CO 2 gas into carbonic acid. The approach consists of investigating the efficiency of nanoparticles in different concentrations of carbonate and mass of nanoparticles. Suitable nanoparticles are proposed based on efficiency and cost in retarding the HCl reactivity and rapid formation of in situ carbonic acid. The concentration of carbonic acid (H 2 CO 3), bicarbonate ion (HCO 3 −), and carbonate ion (CO 3 2−) is analyzed based on Henry's law of solubility. The result shows that the silica has the best efficiency as catalyst in 6700 ppm Na 2 CO 3 solution due to its high stability and dispersion in aqueous solution. The silica engages into rapid dissociation of water molecules and bind with OH − group to react with CO 2 gas and form HCO 3 −. The nanoparticles reduce the reactivity of HCl through conversion of bicarbonate ions. However, ZnO gives better efficiency in 17,000 ppm of Na 2 CO 3. The efficiency of silica in this concentration increased at 0.7 g, proving the minimum amount required as catalyst. In contrast, ZnO and Al 2 O 3 have lower efficiency as acid retarder since changes in pH values affect the performance of the nanoparticles. The surface charge demonstrated by ZnO and Al 2 O 3 depends on pH changes which makes these nanoparticles to perform inefficiently. The silica is chosen as the best catalyst due to high efficiency versus cost ratio.

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“…Al Otaibi et al used two kinds of Aerosil fumed and Ludox colloidal silica nanoparticles to screen the possibility of generating both water-in-CO 2 and CO 2 -in-water emulsions. 48 They used hydrophilic nanoparticles in the water/isooctane system to generate water-in-CO 2 emulsion. The other emulsion, CO 2 -in-water emulsion, was formed using hydrophilic nanoparticles in the same water/isooctane system.…”

Section: Introductionmentioning

confidence: 99%

“…So far, research on the conformance control by CO 2 emulsion is rare. Al Otaibi et al used two kinds of Aerosil fumed and Ludox colloidal silica nanoparticles to screen the possibility of generating both water-in-CO 2 and CO 2 -in-water emulsions . They used hydrophilic nanoparticles in the water/isooctane system to generate water-in-CO 2 emulsion.…”

Section: Introductionmentioning

confidence: 99%

Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO₂ Emulsion on Tertiary Oil Recovery by Supercritical CO₂ Miscible Injection for Carbonate Reservoirs

et al. 2020

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The reservoir heterogeneity is the major cause of poor volumetric sweep efficiency in sandstone and carbonate reservoirs. Displacing fluids (water, chemical solution, gas, and supercritical CO 2 (sc-CO 2 )) flow toward the high permeable zone. A significant fraction of oil remains in the low permeable zone due to the permeability contrast. This study used in situ sc-CO 2 emulsion as a conformance control agent to plug the high permeable zone and improve the low permeable zone's volumetric sweep efficiency in carbonate formation. We investigated the effect of two types of conformance control patterns and the size of sc-CO 2 emulsion on tertiary oil recovery performance by sc-CO 2 miscible injection for carbonate reservoirs at reservoir conditions. The conformance control patterns are achieved using two different approaches. In the first approach, the low permeable zone was isolated, and the diverting gel system, a 0.4 pore volume slug, was injected into a high permeable zone. In the second approach, the simultaneous injection of the diverting gel system, a 0.2 pore volume slug, was done on both the low and high permeable zones. The first sc-CO 2 injection was conducted as a tertiary oil recovery mode to recover the remaining oil after water flooding. The diverting gel system was injected after the first sc-CO 2 flood for the conformance control. The second or post sc-CO 2 injection was conducted after the diverting gel system injection. The diverting gel system used in this study consisted of a polymer and a surfactant. An in situ emulsion was generated when the injected diverting gel system interacts with the sc-CO 2 in the core plug. Results obtained from dual-core core flooding experiments suggested that the in situ sc-CO 2 emulsion was generated successfully in the formation based on the different pressure increases and observation of the dual-core core flooding experiments. The volumetric sweep efficiency and oil recovery in both conformance control patterns were improved. The production performances were also compared for both conformance control models before and after the diverting gel system injection. The conformance control model 2 (simultaneous injection of the diverting gel system into low and high permeability cores) has a better choice to be applied in field application due to high recovery with a small sc-CO2 emulsion easy operation in the field.

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Gelled Emulsions of CO2-Water-Nanoparticles

Cited by 12 publications

References 21 publications

Enhancing the Stability of Foam by the Use of Nanoparticles

Enhancing the Stability of Foam by the Use of Nanoparticles

Experimental study of nanoparticles as catalyst in enhancing matrix acidizing for carbonate reservoir

Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO₂ Emulsion on Tertiary Oil Recovery by Supercritical CO₂ Miscible Injection for Carbonate Reservoirs

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Gelled Emulsions of CO2-Water-Nanoparticles

Cited by 12 publications

References 21 publications

Enhancing the Stability of Foam by the Use of Nanoparticles

Enhancing the Stability of Foam by the Use of Nanoparticles

Experimental study of nanoparticles as catalyst in enhancing matrix acidizing for carbonate reservoir

Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO2 Emulsion on Tertiary Oil Recovery by Supercritical CO2 Miscible Injection for Carbonate Reservoirs

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Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO₂ Emulsion on Tertiary Oil Recovery by Supercritical CO₂ Miscible Injection for Carbonate Reservoirs