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Maiki E, Sun R, Ren S, AlRassas AM. Experimental and Molecular Dynamics Simulation to Investigate Oil Adsorption and Detachment from Sandstone/Quartz Surface by Low-Salinity Surfactant Brines. ACS OMEGA 2024; 9:20277-20292. [PMID: 38737054 PMCID: PMC11079901 DOI: 10.1021/acsomega.4c00562] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Grants] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 01/22/2024] [Revised: 03/27/2024] [Accepted: 04/04/2024] [Indexed: 05/14/2024]
Abstract
In this study, we explore the impact of monovalent (NaCl) and divalent (CaCl2) brines, coupled with sodium dodecyl sulfate (SDS) surfactant at varying low concentrations, on the detachment and displacement of oil from sandstone rock surfaces. Employing the sessile drop method and molecular dynamics simulations, we scrutinize the behavior of the brine solutions. Our findings reveal that both low salinity and low-salinity surfactant solutions induce a gradual shift in rock wettability toward a more water-wet state. This wettability transformation is not instantaneous but evolves over time, as observed through meticulous molecular motion analyses. Through contact angle measurements and molecular dynamics simulations, we delve into the molecular motion at subpore and micropore scales on sandstone/quartz surfaces. The adsorption of surface-active agents from the oil to the oil-brine interface results in a reduced interfacial tension, significantly contributing to oil displacement. Notably, low salinity concentrations ranging from 1000 to 10,000 ppm exhibit the lowest contact angles within 30 min across all solutions. However, higher concentrations deviate from this declining trend, especially with divalent ions like Ca2+, which bridge polar molecules onto the rock surface, resulting in an increased oil-wetting state. This research unveils the intricate molecular motions involved in employing low-salinity surfactant solutions for oil detachment from surfaces. Furthermore, it provides valuable insights into the underlying forces driving oil detachment and wettability alteration.
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Affiliation(s)
- Ernest
Peter Maiki
- School of petroleum Engineering, China University of Petroleum (East China),Qingdao 0086, China
| | - Renyuan Sun
- School of petroleum Engineering, China University of Petroleum (East China),Qingdao 0086, China
| | - Shaoran Ren
- School of petroleum Engineering, China University of Petroleum (East China),Qingdao 0086, China
| | - Ayman Mutahar AlRassas
- School of petroleum Engineering, China University of Petroleum (East China),Qingdao 0086, China
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2
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Zhang J, Wang S, Wang X, Huang B, Zuo M, Chen H. The influence mechanism and the contribution of capillary force and gravity to recovery in spontaneous imbibition in low permeability reservoirs. J DISPER SCI TECHNOL 2023. [DOI: 10.1080/01932691.2023.2177670] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 03/02/2023]
Affiliation(s)
- Jian Zhang
- State Key Laboratory of Offshore Oil Exploitation, Beijing, P.R. China
- CNOOC Research Institute Ltd, Beijing, P.R. China
| | - Shanshan Wang
- State Key Laboratory of Offshore Oil Exploitation, Beijing, P.R. China
- CNOOC Research Institute Ltd, Beijing, P.R. China
| | - Xiujun Wang
- State Key Laboratory of Offshore Oil Exploitation, Beijing, P.R. China
- CNOOC Research Institute Ltd, Beijing, P.R. China
| | - Bo Huang
- State Key Laboratory of Offshore Oil Exploitation, Beijing, P.R. China
- CNOOC Research Institute Ltd, Beijing, P.R. China
| | - Mingsheng Zuo
- State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing), Beijing, China
- College of Safety and Ocean Engineering, China University of Petroleum (Beijing), Beijing, China
| | - Hao Chen
- State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing), Beijing, China
- College of Safety and Ocean Engineering, China University of Petroleum (Beijing), Beijing, China
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3
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Tangparitkul S, Jiang J, Jeraal M, Charpentier TVJ, Harbottle D. Competitive Adsorption of Interfacially Active Nanoparticles and Anionic Surfactant at the Crude Oil-Water Interface. LANGMUIR : THE ACS JOURNAL OF SURFACES AND COLLOIDS 2023; 39:2483-2490. [PMID: 36753535 DOI: 10.1021/acs.langmuir.2c01413] [Citation(s) in RCA: 1] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 06/18/2023]
Abstract
The interfacial activity of poly(N-isopropylacrylamide) (pNIPAM) nanoparticles in the absence and presence of an anionic surfactant (sodium dodecyl sulfate, SDS) was studied at a crude oil-water interface. Both species are interfacially active and can lower the interfacial tension, but when mixed together, the interfacial composition was found to depend on the aging time and total component concentration. With the total component concentration less than 0.005 wt %, the reduced interfacial tension by pNIPAM was greater than SDS; thus, pNIPAM has a greater affinity to partition at the crude oil-water interface. However, the lower molecular weight (smaller molecule) of SDS compared to pNIPAM meant that it rapidly partitioned at the oil-water interface. When mixed, the interfacial composition was more SDS-like for low total component concentrations (≤ 0.001 wt %), while above, the interfacial composition was more pNIPAM-like, similar to the single component response. Applying a weighted arithmetic mean approach, the surface-active contribution (%) could be approximated for each component, pNIPAM and SDS. Even though SDS rapidly partitioned at the oil-water interface, it was shown to be displaced by the pNIPAM nanoparticles, and for the highest total component concentration, pNIPAM nanoparticles were predominantly contributing to the reduced oil-water interfacial tension. These findings have implications for the design and performance of fluids that are used to enhance crude oil production from reservoirs, particularly highlighting the aging time and component concentration effects to modify interfacial tensions.
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Affiliation(s)
- Suparit Tangparitkul
- Department of Mining and Petroleum Engineering, Faculty of Engineering, Chiang Mai University, Chiang Mai 50200, Thailand
| | - Jiatong Jiang
- School of Chemical and Process Engineering, University of Leeds, Leeds LS2 9JT, United Kingdom
| | - Mohammed Jeraal
- Cambridge Centre for Advanced Research and Education in Singapore Ltd., 1 Create Way, CREATE Tower #05-05, 138602 Singapore
| | | | - David Harbottle
- School of Chemical and Process Engineering, University of Leeds, Leeds LS2 9JT, United Kingdom
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Dynamic Interfacial Tensions of Surfactant and Polymer Solutions Related to High-Temperature and High-Salinity Reservoir. Molecules 2023; 28:molecules28031279. [PMID: 36770949 PMCID: PMC9920167 DOI: 10.3390/molecules28031279] [Citation(s) in RCA: 1] [Impact Index Per Article: 1.0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 12/26/2022] [Revised: 01/20/2023] [Accepted: 01/23/2023] [Indexed: 01/31/2023] Open
Abstract
Betaine is a new surfactant with good application prospects in high-temperature and high-salinity reservoirs. The interfacial properties of two kinds of betaine mixtures with a good synergistic effect were evaluated in this paper. On this basis, the effects of temperature-resistant, salt-resistant polymers with different contents of 2-acrylamide-2-methylpropanesulfonic acid (AMPS) on dynamic interfacial tensions (IFTs) against n-alkanes and crude oil were studied. The experimental results show that the IFTs between betaine ASB and n-alkanes can be reduced to ultra-low values by compounding with anionic surfactant petroleum sulfonate (PS) and extended anionic surfactant alkoxyethylene carboxylate (AEC), respectively. ASB@AEC is very oil-soluble with nmin value ≥14, and ASB@PS is relatively water-soluble with nmin value of 10. The water solubility of both ASB@PS and ASB@AEC is enhanced by the addition of water-soluble polymers. The HLB of the ASB@AEC solution becomes better against crude oil after the addition of polymers, and the IFT decreases to an ultra-low value as a result. On the contrary, the antagonistic effect in reducing the IFT can be observed for ASB@PS in the same case. In a word, polymers affect the IFTs of surfactant solutions by regulating the HLB.
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Jiang J, Jackson F, Tangparitkul S, Wilson MCT, Harbottle D. Discontinuous dewetting dynamics of highly viscous droplets on chemically heterogeneous substrates. J Colloid Interface Sci 2023; 629:345-356. [PMID: 36162392 DOI: 10.1016/j.jcis.2022.09.064] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 05/01/2022] [Revised: 09/05/2022] [Accepted: 09/11/2022] [Indexed: 11/22/2022]
Abstract
HYPOTHESIS Droplet spreading on heterogeneous (chemical/structural) surfaces has revealed local disturbances that affect the advancing contact line. With droplet dewetting being less studied, we hypothesize that a receding droplet can be perturbed by localized heterogeneity which leads to irregular and discontinuous dewetting of the substrate. EXPERIMENTS The sessile drop method was used to study droplet dewetting at a wettability boundary. One-half of a hydrophilic surface was hydrophobically modified with either i) methyloctyldichlorosilane or ii) clustered macromolecules. A Lattice Boltzmann method (LBM) simulation was also developed to determine the effect of contact angle hysteresis and boundary conditions on the droplet dynamics. FINDINGS The two surface treatments were optimized to produce comparable water wetting characteristics. With a negative Gibbs free energy on the hydrophilic-half, the oil droplet receded to the hydrophobic-half. On the silanized surface, the droplet was pinned and the resultant droplet shape was a distorted spherical cap, having receded uniformly on the unmodified surface. Modifying the surface with clustered macromolecules, the droplet receded slightly to form a spherical cap. However, droplet recession was non-uniform and daughter droplets formed near the wettability boundary. The LBM simulation revealed that daughter droplets formed when θR > 164°, with the final droplet shape accurately described by imposing a diffuse wettability boundary condition.
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Affiliation(s)
- Jiatong Jiang
- School of Chemical and Process Engineering, University of Leeds, UK
| | | | | | | | - David Harbottle
- School of Chemical and Process Engineering, University of Leeds, UK.
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Effects of brine valency and concentration on oil displacement by spontaneous imbibition: An interplay between wettability alteration and reduction in the oil-brine interfacial tension. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2022.120089] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/20/2022]
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Shahbazi E, Moradzadeh A, Khandoozi S, Riazi M. Experimental investigation of the controversial effects of a cationic surfactant with brine on spontaneous imbibition of an asphaltenic crude oil. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2022.119687] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 10/17/2022]
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Hou J, Lin S, Du J, Sui H. Study of the Adsorption Behavior of Surfactants on Carbonate Surface by Experiment and Molecular Dynamics Simulation. Front Chem 2022; 10:847986. [PMID: 35464211 PMCID: PMC9021538 DOI: 10.3389/fchem.2022.847986] [Citation(s) in RCA: 1] [Impact Index Per Article: 0.5] [Reference Citation Analysis] [Abstract] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 01/04/2022] [Accepted: 02/28/2022] [Indexed: 11/13/2022] Open
Abstract
Surfactants adsorption onto carbonate reservoirs would cause surfactants concentrations decrease in surfactant flooding, which would decrease surfactant efficiency in practical applications of enhanced oil recovery (EOR) processes. Different surfactants could be classified as cationic surfactants, anionic surfactants, non-ionic surfactants according to the main charge, or be classified as chemical surfactant and bio-surfactant according to the surfactant origin. However, the research on different type surfactants adsorption on carbonate reservoirs surface differences was few. Therefore, five representative surfactants (CTAB, SDS, TX-100, sophorolipid, rhamonilipid) adsorption effect onto carbonate reservoirs surface was studied. Owing to the fact that the salinity and temperature in underground carbonate reservoirs were high during the EOR process, it is vital to study the salinity effect and temperature effect on surfactant adsorption. In this study, different surfactants species, temperature and salinity adsorption onto carbonate reservoirs were studied. The adsorption isotherms were fitted by Langmuir, Freundlich, Temkin and Linear models, and the first three models fitting effect were good. The results showed that cationic surfactants adsorption quantity was higher than anionic surfactants, and the non-ionic surfactants adsorption quantity was the lowest. When the temperature increased, the surfactants adsorption would decrease, because the adsorption process was exothermic process, and increasing temperature would inhibit the adsorption. The higher salinity would increase surfactants adsorption because higher salinity could compress electric double layer. In order to decrease surfactants adsorption, SiO2 nanoparticles and TiO2 nanoparticles were added to surfactants solutions, and then surfactants could adsorb onto nanoparticles surface, then the steric hindrance between surfactant molecules would increase, which could decrease surfactants adsorption. Contact angle results indicated that surfactants adsorption made the carbonate reservoir wettability alteration. In the end, surfactants (with or without SiO2 nanoparticles) adsorption onto carbonate reservoirs mechanism were studied by molecular dynamics simulation. The simulation results indicated that the surfactants molecules could adsorb onto SiO2 nanoparticles surface, and then the surfactants adsorption quantity onto carbonate rocks would decrease, which was in accordance with the experiments results.
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Affiliation(s)
- Jinjian Hou
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
- Collaborative Innovation Center of Chemical Science and Engineering, Tianjin, China
| | - Shuanglong Lin
- School of Chemical Engineering, Shijiazhuang University, Shijiazhuang, China
| | - Jinze Du
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
- *Correspondence: Jinze Du, ; Hong Sui,
| | - Hong Sui
- School of Chemical Engineering and Technology, Tianjin University, Tianjin, China
- National Engineering Research Centre of Distillation Technology, Tianjin, China
- Collaborative Innovation Center of Chemical Science and Engineering, Tianjin, China
- *Correspondence: Jinze Du, ; Hong Sui,
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Jiang J, Kang X, Wu H, Lu Y, Li Z, Xu D, Ma T, Yang H, Kang W. Spontaneous emulsification induced by a novel surfactant-polymer compound system and its application to enhance oil recovery. J Mol Liq 2021. [DOI: 10.1016/j.molliq.2021.116399] [Citation(s) in RCA: 5] [Impact Index Per Article: 1.7] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/27/2022]
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Dewetting dynamics of heavy crude oil droplet in low-salinity fluids at elevated pressures and temperatures. J Colloid Interface Sci 2021; 596:420-430. [PMID: 33848746 DOI: 10.1016/j.jcis.2021.03.130] [Citation(s) in RCA: 8] [Impact Index Per Article: 2.7] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 01/19/2021] [Revised: 03/20/2021] [Accepted: 03/22/2021] [Indexed: 11/22/2022]
Abstract
HYPOTHESIS Improved oil recovery by low-salinity injection correlates to the optimal brine concentration to achieve maximum dewetting of oil droplets on rock surfaces. While interfacial tension and electrical double layer forces are often cited as being determinant properties, we hypothesize that other structural/interfacial forces are more prominent in governing the system behavior. EXPERIMENTS The sessile droplet technique was used to study the receding dynamics of oil droplets from flat hydrophilic substrates in brines of different salt type (NaCl and CaCl2) and concentration, and were studied at both low and elevated temperatures (60 and 140 °C) and pressures (1, 10, 100 and 200 bar). FINDINGS At 1 bar and 60 °C, the minimum oil droplet-substrate adhesion force (FA) was determined at 34 mM NaCl and 225 mM CaCl2. For NaCl this strongly correlated to strengthening hydration forces, which for CaCl2 were diminished by long-range hydrophobic forces. These results highlight the importance of other non-DLVO forces governing the dewetting dynamics of heavy crude oil droplets. At 140 °C and 200 bar, the optimal brine concentrations were found to be much higher (1027 mM NaCl and 541 mM CaCl2), with higher concentrations likely attributed to weakening hydration forces at elevated temperatures.
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Abstract
Nanoparticles (NPs) have been proposed for enhanced oil recovery (EOR). The research has demonstrated marvelous effort to realize the mechanisms of nanoparticles EOR. Nevertheless, gaps still exist in terms of understanding the nanoparticles-driven interactions occurring at fluids and fluid–rock interfaces. Surface-active polymers or other surface additive materials (e.g., surfactants) have shown to be effective in aiding the dispersion stability of NPs, stabilizing emulsions, and reducing the trapping or retention of NPs in porous media. These pre-requisites, together with the interfacial chemistry between the NPs and the reservoir and its constituents, can result in an improved sweep efficiency. This paper investigates four types of polymer-coated silica NPs for the recovery of oil from water-wet Berea sandstones. A series of flooding experiments was carried out with NPs dispersed at 0.1 wt.% in seawater in secondary and tertiary oil recovery modes at ambient conditions. The dynamic interactions of fluids, fluid–rock, and the transport behavior of injected fluid in the presence of NPs were, respectively, studied by interfacial tension (IFT), spontaneous imbibition tests, and a differential pressure analysis. Core flooding results showed an increase in oil recovery up to 14.8% with secondary nanofluid injection compared to 39.7% of the original oil in place (OOIP) from the conventional waterflood. In tertiary mode, nanofluids increased oil recovery up to 9.2% of the OOIP. It was found that no single mechanism could account for the EOR effect with the application of nanoparticles. Instead, the mobilization of oil seemed to occur through a combination of reduced oil/water IFT, change in the rock surface roughness and wettability, and microscopic flow diversion due to clogging of the pores.
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Lu Y, Li R, Manica R, Liu Q, Xu Z. Enhancing oil–solid and oil–water separation in heavy oil recovery by
CO
2
‐responsive surfactants. AIChE J 2020. [DOI: 10.1002/aic.17033] [Citation(s) in RCA: 10] [Impact Index Per Article: 2.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 12/24/2022]
Affiliation(s)
- Yi Lu
- Department of Chemical and Materials Engineering University of Alberta Edmonton Alberta Canada
| | - Rui Li
- Department of Chemical and Materials Engineering University of Alberta Edmonton Alberta Canada
| | - Rogerio Manica
- Department of Chemical and Materials Engineering University of Alberta Edmonton Alberta Canada
| | - Qingxia Liu
- Department of Chemical and Materials Engineering University of Alberta Edmonton Alberta Canada
| | - Zhenghe Xu
- Department of Chemical and Materials Engineering University of Alberta Edmonton Alberta Canada
- Department of Materials Science and Engineering Southern University of Science and Technology Shenzhen China
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Luan H, Gong L, Yue X, Nie X, Chen Q, Guan D, Que T, Liao G, Su X, Feng Y. Micellar Aggregation Behavior of Alkylaryl Sulfonate Surfactants for Enhanced Oil Recovery. Molecules 2019; 24:molecules24234325. [PMID: 31779282 PMCID: PMC6930474 DOI: 10.3390/molecules24234325] [Citation(s) in RCA: 8] [Impact Index Per Article: 1.6] [Reference Citation Analysis] [Abstract] [Key Words] [MESH Headings] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 06/04/2019] [Revised: 11/07/2019] [Accepted: 11/25/2019] [Indexed: 11/24/2022] Open
Abstract
Alkylaryl sulfonate is a typical family of surfactants used for chemically enhanced oil recovery (EOR). While it has been widely used in surfactant–polymer flooding at Karamay Oilfield (40 °C, salinity 14,000 mg/L), its aggregation behavior in aqueous solutions and the contribution of aggregation to EOR have not been investigated so far. In this study, raw naphthenic arylsulfonate (NAS) and its purified derivatives, alkylaryl monosulfonate (AMS) and alkylaryl disulfonate (ADS), were examined under simulated temperature and salinity environment of Karamay reservoirs for their micellar aggregation behavior through measuring surface tension, micellar size, and micellar aggregation number. It was found that all three alkylaryl sulfonate surfactants could significantly lower the surface tension of their aqueous solutions. Also, it has been noted that an elevation both in temperature and salinity reduced the surface tension and critical micellar concentration. The results promote understanding of the performance of NAS and screening surfactants in EOR.
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Affiliation(s)
- Huoxin Luan
- Experimental Detection Research Institute, Xinjiang Oilfield Company, Karamay 834000, China; (H.L.); (X.N.); (Q.C.); (D.G.); (T.Q.)
| | - Lingyan Gong
- Polymer Research Institute, State Key Laboratory of Polymer Materials Engineering, Sichuan University, Chengdu 610065, China;
| | - Xinjian Yue
- Experimental Detection Research Institute, Xinjiang Oilfield Company, Karamay 834000, China; (H.L.); (X.N.); (Q.C.); (D.G.); (T.Q.)
| | - Xiaobin Nie
- Experimental Detection Research Institute, Xinjiang Oilfield Company, Karamay 834000, China; (H.L.); (X.N.); (Q.C.); (D.G.); (T.Q.)
| | - Quansheng Chen
- Experimental Detection Research Institute, Xinjiang Oilfield Company, Karamay 834000, China; (H.L.); (X.N.); (Q.C.); (D.G.); (T.Q.)
| | - Dan Guan
- Experimental Detection Research Institute, Xinjiang Oilfield Company, Karamay 834000, China; (H.L.); (X.N.); (Q.C.); (D.G.); (T.Q.)
| | - Tingli Que
- Experimental Detection Research Institute, Xinjiang Oilfield Company, Karamay 834000, China; (H.L.); (X.N.); (Q.C.); (D.G.); (T.Q.)
| | - Guangzhi Liao
- PetroChina Exploration & Production Company, Beijing 100007, China;
| | - Xin Su
- Polymer Research Institute, State Key Laboratory of Polymer Materials Engineering, Sichuan University, Chengdu 610065, China;
- Correspondence: (X.S.); (Y.F.)
| | - Yujun Feng
- Polymer Research Institute, State Key Laboratory of Polymer Materials Engineering, Sichuan University, Chengdu 610065, China;
- Correspondence: (X.S.); (Y.F.)
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14
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Colloids and Interfaces in Oil Recovery. COLLOIDS AND INTERFACES 2019. [DOI: 10.3390/colloids3020050] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 11/17/2022]
Abstract
The role of surface and colloid chemistry in the petroleum industry is of great importance to the many current and future challenges confronting this sector [...]
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