Effect of injection brine composition on wettability and oil recovery in sandstone reservoirs

Hua, Zhao; Li, Mingyuan; Ni, Xiaoxiao; Wang, Haoyi; Yang, Zihao; Lin, Meiqin

doi:10.1016/j.fuel.2016.06.009

Cited by 49 publications

(23 citation statements)

References 24 publications

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“…In this paper, contact angle measurements were performed under a liquid situation to weaken the disturbance (Figure ). This method has been popularly applied to determine the contact angle. , A water tank was filled with an NaCl solution (0.05 mol/L). Oil (2.5 μL) was released using a microsyringe with a U-shaped needle.…”

Section: Methodsmentioning

confidence: 99%

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Experimental Investigation of the Role of DC Voltage in the Wettability Alteration in Tight Sandstones

et al. 2020

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The usage of direct current (DC) voltage has enormous potential for oil fields due to the effect of wettability alteration. However, the unclear mechanism of the wettability alteration has limited the application of this technology to oil fields. In this study, chemical and physical methods including contact angle tests, Fourier-transform infrared spectroscopy (FTIR) measurements, and atomic force microscope (AFM) experiments were combined to investigate the wettability alteration mechanism for tight sandstones subjected to DC voltage treatment. From the view of a chemical factor, FTIR results show that DC voltage decreases the number of Si–O–Si, C–O–C, C–O, and COOH groups, while it also increases the number of CO and OH groups. The changes in molecular groups further improve the water-wetting property of tight sandstones. On the other hand, in a physical way, AFM results indicate that DC voltage improves the roughness of the rock surface. At the same time, the wetting state transfers from the Cassie–Baxter to the Wenzel. This increases the contact area of the solid–liquid interface. The augment of roughness and the transfer of the wetting state improve the water-wetting property of tight sandstones. By comparing the influences of both chemical and physical factors on wettability, it is concluded that although roughness indeed affects the wettability, chemical factors play a dominant role in determining the wettability. Achievements in this study can help researchers and engineers better understand the mechanism of wettability alteration and further accelerate the development of tight sandstones with DC voltage-related technology.

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Section: Methodsmentioning

confidence: 99%

“…This method has been popularly applied to determine the contact angle. 50,51 A water tank was filled with an NaCl solution (0.05 mol/L). Oil (2.5 μL) was released using a microsyringe with a U-shaped needle.…”

Section: ■ Experimental Sectionmentioning

confidence: 99%

Experimental Investigation of the Role of DC Voltage in the Wettability Alteration in Tight Sandstones

et al. 2020

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“…The unmovable residual oil attached to the pore wall starts moving towards the downstream direction along with pore wall carried by polymer solution and then gathered at the other side of rock particle. When the oil film attached to the pore wall accumulated to a certain amount, a ''bridge'' appears between rock particles that allow oil moving from upstream to downstream and further be exploited, which was also called ''bridge effect'' (Hua et al, 2016). Although this phenomenon looks similar to low interfacial tension phenomenon, the real observation documents indicate that there is not a significant difference between the interfacial tension between polymer solution and crude oil at 0.012 N/m and the oil-water interfacial tension at 0.015 N/m.…”

Section: Polymer Flooding Mechanism and Remaining Oil Distribution Chmentioning

confidence: 99%

Differences of microscopic seepage mechanisms of water flooding and polymer flooding and prediction models of final oil recovery for conglomerate reservoir

Tan¹,

Xu²,

Zhang³

et al. 2019

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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The special sedimentary environments of conglomerate reservoir lead to pore structure characteristics of complex modal, and the reservoir seepage system is mainly in the “sparse reticular-non reticular” flow pattern. As a result, the study on microscopic seepage mechanism of water flooding and polymer flooding and their differences becomes the complex part and key to enhance oil recovery. In this paper, the actual core samples from conglomerate reservoir in Karamay oilfield are selected as research objects to explore microscopic seepage mechanisms of water flooding and polymer flooding for hydrophilic rock as well as lipophilic rock by applying the Computed Tomography (CT) scanning technology. After that, the final oil recovery models of conglomerate reservoir are established in two displacement methods based on the influence analysis of oil displacement efficiency. Experimental results show that the seepage mechanisms of water flooding and polymer flooding for hydrophilic rock are all mainly “crawling” displacement along the rock surface while the weak lipophilic rocks are all mainly “inrushing” displacement along pore central. Due to the different seepage mechanisms among the water flooding and the polymer flooding, the residual oil remains in hydrophilic rock after water flooding process is mainly distributed in fine throats and pore interchange. These residual oil are cut into small droplets under the influence of polymer solution with stronger shearing drag effect. Then, those small droplets pass well through narrow throats and move forward along with the polymer solution flow, which makes enhancing oil recovery to be possible. The residual oil in weak lipophilic rock after water flooding mainly distributed on the rock particle surface and formed oil film and fine pore-throat. The polymer solution with stronger shear stress makes these oil films to carry away from particle surface in two ways such as bridge connection and forming oil silk. Because of the essential attributes differences between polymer solution and injection water solution, the impact of Complex Modal Pore Structure (CMPS) on the polymer solution displacement and seepage is much smaller than on water flooding solution. Therefore, for the two types of conglomerate rocks with different wettability, the pore structure is the main controlling factor of water flooding efficiency, while reservoir properties oil saturation, and other factors have smaller influence on flooding efficiency although the polymer flooding efficiency has a good correlation with remaining oil saturation after water flooding. Based on the analysis on oil displacement efficiency factors, the parameters of water flooding index and remaining oil saturation after water flooding are used to establish respectively calculation models of oil recovery in water flooding stage and polymer flooding stage for conglomerate reservoir. These models are able to calculate the oil recovery values of this area controlled by single well control, and further to determine the oil recovery of whole reservoir in different displacement stages by leveraging interpolation simulation methods, thereby providing more accurate geological parameters for the fine design of displacement oil program.

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“…Therefore, the behavior of fluid in tight reservoir still awaits to be revealed. To investigate the fluid performance in tight clastic rock reservoir, some experiments and studies returned back to the essential issues, including the pore-throat structure and physical interaction of fluid-pore-wall in the tight reservoir [6,10,13,[15][16][17][18][19][20][21][22][23][24]. However, the pore-throat structures are various significantly in tight clastic rock reservoir and the fluid flow inside needs to be particularly concerned [25][26][27][28][29].…”

Section: Introductionmentioning

confidence: 99%

The Controls of Pore-Throat Structure on Fluid Performance in Tight Clastic Rock Reservoir: A Case from the Upper Triassic of Chang 7 Member, Ordos Basin, China

et al. 2018

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The characteristics of porosity and permeability in tight clastic rock reservoir have significant difference from those in conventional reservoir. The increased exploitation of tight gas and oil requests further understanding of fluid performance in the nanoscale pore-throat network of the tight reservoir. Typical tight sandstone and siltstone samples from Ordos Basin were investigated, and rate-controlled mercury injection capillary pressure (RMICP) and nuclear magnetic resonance (NMR) were employed in this paper, combined with helium porosity and air permeability data, to analyze the impact of pore-throat structure on the storage and seepage capacity of these tight oil reservoirs, revealing the control factors of economic petroleum production. The researches indicate that, in the tight clastic rock reservoir, largest throat is the key control on the permeability and potentially dominates the movable water saturation in the reservoir. The storage capacity of the reservoir consists of effective throat and pore space. Although it has a relatively steady and significant proportion that resulted from the throats, its variation is still dominated by the effective pores. A combination parameter ( ) that was established to be as an integrated characteristic of pore-throat structure shows effectively prediction of physical capability for hydrocarbon resource of the tight clastic rock reservoir.

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Effect of injection brine composition on wettability and oil recovery in sandstone reservoirs

Cited by 49 publications

References 24 publications

Experimental Investigation of the Role of DC Voltage in the Wettability Alteration in Tight Sandstones

Experimental Investigation of the Role of DC Voltage in the Wettability Alteration in Tight Sandstones

Differences of microscopic seepage mechanisms of water flooding and polymer flooding and prediction models of final oil recovery for conglomerate reservoir

The Controls of Pore-Throat Structure on Fluid Performance in Tight Clastic Rock Reservoir: A Case from the Upper Triassic of Chang 7 Member, Ordos Basin, China

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