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Experimental study of surfactant-enhanced spontaneous Imbibition in fractured tight sandstone reservoirs: The effect of fracture distribution

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Petroleum Science 2023年第1期20卷 370-381页

作者： Kun Yang Fu-Yong Wang Jiu-Yu Zhao State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum(Beijing)Beijing102249P.R.China College of Petroleum Engineering China University of Petroleum(Beijing)Beijing102249P.R.China College of Artificial Intelligence China University of Petroleum(Beijing)Beijing102249P.R.China College of Geosciences China University of Petroleum(Beijing)Beijing102249P.R.China

Spontaneous Imbibition is an important phenomenon in tight reservoirs.The existence of a large number of fractures and micro-nano pores is the key factor affecting the spontaneous Imbibition of tight reservoirs.In this study,based on high-pressure mercury injection and nuclear magnetic resonance experiments,the pore distribution of tight sandstone is described.The influence of fractures,core porosity and permeability,and surfactants on the spontaneous Imbibition of tight sandstone are studied by physical fracturing,interfacial tension test,wettability test and Imbibition experiments.The results show that:the pore radius of tight sandstone is concentrated in 0.01-1 mm.Fractures can effectively reduce the oil drop adsorption on the core surface,enhancing the Imbibition recovery of the tight sandstone with an increase of about 10%.As the number of fractures increases,the number of oil droplets adsorbed on the core surface decrease and the Imbibition rate increases.The Imbibition recovery increases with the increase in pore connectivity,while the Imbibition rate increases with the increases in core porosity and permeability.The surfactant can improve the core water wettability and reduce the oilwater interfacial tension,reducing the adsorption of oil droplets on the core surface,and improving the core Imbibition recovery with an increase of about 15%.In a word,the existence of fractures and surfactants can enhance the pore connectivity of the reservoir,reduce the adsorption of oil droplets on the core surface,and improve the Imbibition rate and recovery rate of the tight oil reservoir.

关键词： Tight sandstone Imbibition Fracture Surfactant

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Analysis of Imbibition of n-alkanes in kerogen slits by molecular dynamics simulation for characterization of shale oil rocks

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Petroleum Science 2022年第3期19卷 1236-1249页

作者： Qian Sang Xin-Yi Zhao Hui-Min Liu Ming-Zhe Dong Key Laboratory of Unconventional Oil&Gas Development(China University of Petroleum(East China)) Ministry of EducationQingdao266580ShandongChina School of Petroleum Engineering China University of Petroleum(East China)Qingdao266580ShandongChina Management Center of Oil&Gas Exploration of Shengli Oilfield Branch Company SINOPECDongying257001ShandongChina Department of Chemical and Petroleum Engineering University of CalgaryCalgaryABCanadaT2N 1N4

Shale oil formations contain both inorganic and organic media.The organic matter holds both free oil in the pores and dissolved oil within the kerogen molecules.The free oil flow in organic pores and the dissolved oil diffusion in kerogen molecules are coupled together.The molecular flow of free n-alkanes is an important process of shale oil accumulation and production.To study the dynamics of Imbibition process of n-alkane molecules into kerogen slits,molecular dynamics(MD)simulations are conducted.Effects of slit width,temperature,and n-alkane types on the penetration speed,dynamic contact angle,and molecular conformations were analyzed.Results showed that molecular transportation of n-alkanes is dominated by molecular structure and molecular motion at this scale.The space-confinement conformational changes of molecules slow down the filling speeds in the narrow slits.The n-alkane molecules with long carbon chains require more time to undergo conformational changes.The high content of short-chain alkanes and high temperature facilitate the flow of alkane mixtures in kerogen slits.Results obtained from this study are useful for understanding the underlying nanoscale flow mechanism in shale formations.

关键词： Molecular flow Imbibition n-Alkane Kerogen slit Molecular dynamics simulation

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Core-scale modeling of surfactant-assisted spontaneous water Imbibition in carbonates

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Petroleum 2022年第4期8卷 458-465页

作者： Xingang Bu Ming Han Abdulkareem M.AlSofi Beijing Research Center Aramco AsiaBeijing100102China EXPEC Advanced Research Center Saudi AramcoDhahran31311Saudi Arabia

This work numerically investigates surfactant effects on spontaneous water Imbibition in oil-wet carbonates.An open boundary core-scale Imbibition model with 9×9×10 gridblocks was used in UTCHEM to simulate carbonate core plug exposure to a vast water body.The simulation models were developed based on surfactant-assisted Imbibition tests that were conducted in secondary and tertiary oil production modes using Amott cells at 75℃.Capillary and gravity forces were captured by history matching the experiments.Through history matching,the inputs for surfactant adsorption and diffusion,capillary pressure and relative permeability were calibrated.In tertiary mode,the surfactants-assisted Imbibition process presents the performance in mixed-wet state rather than oil-wet state,which is governed by wettability alteration.A simulation model for surfactant-assisted Imbibition in secondary mode was used to investigate the effects of various factors including interfacial tension(IFT)reduction,wettability alteration,adsorption,volume of surrounding water and capillary force.The simulation results suggest that surfactant-assisted water Imbibition in secondary mode is gravity dominant,which is facilitated by both IFT reduction and wettability alteration caused by addition of proper surfactants.Different from water Imbibition in water-wet core,it presents vertically dominant oil flow with a hemispherical oil-rich area and uneven remaining oil saturation.It is obvious that sufficient surfactant supply in vast water is required to make effective Imbibition,in consideration of surfactant consumption and changes in concentration gradients.This core-scale modeling provides insights of surfactant-assisted Imbibition in initially oil-wet carbonates and helps scale up the application in a cost-effective way.

关键词： Surfactant Imbibition Core-scale modeling Simulation Wettability alteration Interfacial tension

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Features and Imbibition mechanisms of Winsor Ⅰ type surfactant solution in oil-wet porous media

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Petroleum Exploration and Development 2019年第5期46卷 1006-1013页

作者： YU Fuwei JIANG Hanqiao FAN Zhen XU Fei SU Hang CHENG Baoyang LIU Rengjing LI Junjian State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249China SINOPEC International Petroleum Exploration&Production Corporation Beijing 100029China

The relationship between NaCl concentration and the phase change behavior of microemulsion of anionic surfactant was characterized by the salinity scan experiments.The wettability of WinsorⅠtype surfactant solution(WⅠsolution)and the effect of NaCL concentration on phase change behavior of WⅠsolution and Imbibition in oil-wet porous media were investigated by microfluidic experiments in this study.The WⅠsolution and WinsorⅠtype microemulsion are similar in wetting phase with stronger wettability than other phases.Two main mechanisms of WⅠsolution enhancing Imbibitions recovery in oil wet porous media are the wetting phase drive and residual oil solubilization.Under the salinity condition of WinsorⅠtype microemulsion,the NaCl concentration has strong impact on the Imbibition mechanism of WⅠsolution,the higher the NaCl concentration,the complex the Imbibition process and the higher the Imbibition efficiency will be.The NaCl concentration has strong impact on the solubilization ability to oil of the WⅠsolution,the higher the NaCl concentration,the stronger the solubility of the WⅠsolution to residual oil will be.

关键词： porous media wettability WinsorⅠtype surfactant Imbibition mechanism enhanced oil recovery

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Performance comparison of novel chemical agents in improving oil recovery from tight sands through spontaneous Imbibition

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Petroleum Science 2020年第2期17卷 409-418页

作者： Hai Huang Tayfun Babadagli Xin Chen Huazhou Andy Li College of Petroleum Engineering and Shaanxi Key Laboratory of Advanced Stimulation Technology for Oil and Gas Reservoirs Xi’an Shiyou UniversityXi’an 710065People’s Republic of China School of Mining and Petroleum Engineering Faculty of EngineeringUniversity of AlbertaEdmonton T6G 1H9Canada

Tight sands are abundant in nanopores leading to a high capillary pressure and normally a low fluid injectivity.As such,spontaneous Imbibition might be an effective mechanism for improving oil recovery from tight sands after fracturing.The chemical agents added to the injected water can alter the interfacial properties,which could help further enhance the oil recovery by spontaneous Imbibition.This study explores the possibility of using novel chemicals to enhance oil recovery from tight sands via spontaneous Imbibition.We experimentally examine the effects of more than ten different chemical agents on spontaneous Imbibition,including a cationic surfactant(C12 TAB),two anionic surfactants(0242 and 0342),an ionic liquid(BMMIM BF4),a high pH solution(NaBO2),and a series of house-made deep eutectic solvents(DES3-7,9,11,and 14).The interfacial tensions(IFT)between oil phase and some chemical solutions are also determined.Experimental results indicate that both the ionic liquid and cationic surfactant used in this study are detrimental to spontaneous Imbibition and decrease the oil recovery from tight sands,even though cationic surfactant significantly decreases the oil-water IFT while ionic liquid does not.The high pH NaBO2 solution does not demonstrate significant effect on oil recovery improvement and IFT reduction.The anionic surfactants(O242 and O342)are effective in enhancing oil recovery from tight sands through oil-water IFT reduction and emulsification effects.The DESs drive the rock surface to be more water-wet,and a specific formulation(DES9)leads to much improvement on oil recovery under counter-current Imbibition condition.This preliminary study would provide some knowledge about how to optimize the selection of chemicals for improving oil recovery from tight reservoirs.

关键词： Spontaneous Imbibition Novel chemical agent Water flooding Tight sands

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Isolation and Expression Profile Analysis of Genes Relevant to Chilling Stress During Seed Imbibition in Soybean [Glycine max (L.) Meer.]

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Agricultural Sciences in China 2009年第5期8卷 521-528页

作者： CHENG Li-bao LI Shu-yan HE Guang-yuan China-UK HUST-RRes Genetic Engineering and Genomics Joint Laboratory/Key Laboratory of Molecular Biophysics Ministry of Education/College of Life Science and Technology Huazhong University of Science and Technology Wuhan 430074 P.R. China Life Science and Technique College Xiaogan University Xiaogan 432000 P.R.China

Germination of soybean seed is always arrested by chilling Imbibitional stress, and this phenomenon is widespread in the plant seed kingdom, but has not been studied at molecular level. In this experiment, cDNA-amplified fragment length polymorphism （cDNA-AFLP） technique was applied to isolate genes relevant to chilling stress （4℃） during soybean seed Imbibition. Eight genes were found to be up-regulated and two were down-regulated during chilling stress respectively. Four up-regulated genes were selected to analyze the expression profiles during Imbibition under chilling condition. It was demonstrated that the four genes were induced significantly by 4℃ for 24 h, and decreased when the temperature was shifted from 4 to 22℃. GMCHl, a highly chilling stress-induced gene which responded to abscisic acid （ABA）, polyethylene glycol （PEG） and NaCl, showed great stress-resistance according to published reports. Cos78 was identified to be induced by PEG. However, Cos66 and Cos36 transcription showed no change to ABA, PEG, and NaCl. From the characteristic of genes isolated from the embryonic axis, we concluded that soybean seeds have different pathways to adapt to various biotic and abiotic stresses by regulating many signal transduction pathways.

关键词： soybean germination Imbibition stress cDNA-AFLP

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Effects of the Imbibition Ability of Extinguishant in Pulverized Coals

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Transactions of Tianjin University 2019年第1期25卷 45-51页

作者： Liyan Liu Haoshuang Gong Xin Shi Dong Lv Wei Tan Guorui Zhu School of Chemical Engineering and Technology Tianjin University Key Laboratory of Building Fire Protection Engineering and Technology of MPS

The Imbibition ability of extinguishant is an important factor influencing the extinguishing effect for smoldering fire in pulverized coals. The coal particle size, bulk compactness, and aqueous solution properties significantly affect the Imbibition ability of extinguishment. This work aims to reveal the influence of the properties of pulverized coals and aqueous solution on the Imbibition ability of extinguishant for smoldering fire through experiments and capillary theories. The Imbibition height and rate were adopted to evaluate the Imbibition ability of extinguishment. The results showed that a relatively small bulk compactness and a fine coal particle size negatively influenced the extinguishing process dominantly because of its high surface energy and low wettability. An additive was used to adjust the properties of aqueous solution. The liquid with a larger surface tension, a smaller contact angle, and a lower viscosity induced a better Imbibition ability of extinguishment.

关键词： Pulverized coal Smoldering fire Imbibition ability Capillary theories

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Effect of electroosmotic flow on brine Imbibition in porous media

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Water Science and Engineering 2009年第1期2卷 103-111页

作者： Rui WANG Xiang-an YUE Xu WEI Wei ZHANG MOE Key Laboratory of Petroleum Engineering China University of Petroleum Beijing 102249 P. R. China Bohai Oil Material Supply Company Tianjin 300450 P. R. China China Huayou Group Corporation Beijing 100011 P. R. China

Based on Darcy＇s Law and the Helmholta-Smoluchowski equation, an Imbibition velocity formula for the water phase with an electric field was deduced, showing that the Imbibition velocity with an electric field is to various extents not only related to the rock permeability and characteristic length, the fluid viscosity, the oil-water interface tension and the gravity of the imbibing brine, but also to the fluid dielectric permittivity, zeta potential, applied electric field direction, and strength. Imbibition experiments with electric fields that are different in direction and strength were conducted, showing that application of a positive electric field enhances the Imbibition velocity and increases the Imbibition recovery ratio, while application of a negative electric field reduces the Imbibition velocity and decreases the Imbibition recovery ratio. The Imbibition recovery ratio with a positive electric field increases with the strength of the electric field, and the Imbibition recovery ratio with a negative electric field is lower than that without an electric field.

关键词： Imbibition Imbibition velocity electroosmotic flow electric field direction electric field strength

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A new interacting capillary bundle model on the multiphase flow in micropores of tight rocks

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PETROLEUM SCIENCE 2024年第2期21卷 1099-1112页

作者： Deng, Wen-Quan Liang, Tian -Bo Wang, Wen-Zhong Liu, Hao Wu, Jun -Lin Zhou, Fu-Jian China Univ Petr Natl Key Lab Petr Resources & Engn Beijing 102249 Peoples R China

Surfactants are widely used in the fracturing fluid to enhance the Imbibition and thus the oil recovery rate. However, current numerical models cannot capture the physics behind capillary Imbibition during the wettability alteration by surfactants. Although the interacting capillary bundle (ICB) model shows potential in characterizing Imbibition rates in different pores during wettability alteration, the existing ICB models neglect the influence of wettability and viscosity ratio on the Imbibition behavior, making it difficult to accurately describe the oil-water Imbibition behavior within the porous media. In this work, a new ICB mathematical model is established by introducing pressure balance without assuming the position of the leading front to comprehensively describe the Imbibition behavior in a porous medium under different conditions, including gas-liquid spontaneous Imbibition and oil-water Imbibition. When the pore size distribution of a tight rock is known, this new model can predict the changes of water saturation during the displacement process in the tight rock, and also determine the Imbibition rate in pores of different sizes. The water saturation profiles obtained from the new model are validated against the waterflooding simulation results from the CMG, while the Imbibition rates calculated by the model are validated against the experimental observations of gas-liquid spontaneous Imbibition. The good match above indicates the newly proposed model can show the water saturation profile at a macroscopic scale while capture the underlying physics of the multiphase flow in a porous medium at a microscopic scale. Simulation results obtained from this model indicate that both wettability and viscosity ratio can affect the sequence of fluid Imbibition into pores of different sizes during the multiphase flow, where less-viscous wetting fluid is preferentially imbibed into larger pores while more-viscous wetting fluid tends to be imbibed into smaller pores. Furthermore, this model provides an avenue to ca

关键词： Imbibition Multiphase flow Tight rock Interacting capillary bundle model Wettability OIL-RECOVERY EOR SPONTANEOUS Imbibition IMMISCIBLE DISPLACEMENT SATURATION RESERVOIR TUBES MECHANISM

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A novel responsive stabilizing Janus nanosilica as a nanoplugging agent in water-based drilling fluids for exploiting hostile shale environments

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PETROLEUM SCIENCE 2024年第2期21卷 1190-1210页

作者： Tchameni, Alain Pierre Zhuo, Lv-Yan Djouonkep, Lesly Dasilva Wandji Nagre, Robert Dery Chen, Lu-Xin Zhao, Lin Ma, Chao Xie, Bin-Qiang Yangtze Univ Coll Petr Engn Wuhan 430100 Hubei Peoples R China Key Lab Drilling & Prod Engn Oil & Gas Hubei Peoples R China Yangtze Univ Lost Circulat Control Lab Natl Engn Lab Petr Drilling Engn Wuhan 430100 Hubei Peoples R China Shandong Inst Petr & Chem Technol Coll Petr Engn Dongying 257061 Shandong Peoples R China Petr Engineer Res Inst Petrochina Dagang Oilfield Tianjin 300280 Peoples R China Kumasi Tech Univ Dept Chem Engn POB 854 Kumasi Ghana

Thermo -responsive nanocomposites have recently emerged as potential nanoplugging agents for shale stabilization in high -temperature water -based drilling fluids (WBDFs). However, their inhibitory properties have not been very effective in high -temperature drilling operations. Thermo -responsive Janus nanocomposites are expected to strongly interact with clay particles from the inward hemisphere of nanomaterials, which drive the establishment of a tighter hydrophobic membrane over the shale surface at the outward hemisphere under geothermal conditions for shale stabilization. This work combines the synergistic bene fits of thermo-responsive and zwitterionic nanomaterials to synchronously enhance the chemical inhibitions and plugging performances in shale under harsh conditions. A novel thermoresponsive Janus nanosilica (TRJS) exhibiting zwitterionic character was synthesized, characterized, and assessed as shale stabilizer for WBDFs at high temperatures. Compared to pristine nanosilica (SiNP) and symmetrical thermo-responsive nanosilica (TRS), TRJS exhibited anti-polyelectrolyte behaviour, in which electrolyte ions screened the electrostatic attraction between the charged particles, potentially stabilizing nanomaterial in hostile shaly environments (i.e., up to saturated brine or API brine). Macroscopically, TRJS exhibited higher chemical inhibition than SiNP and TRS in brine, prompting a better capability to control pressure penetration. TRJS adsorbed onto the clay surface via chemisorption and hydrogen bonding, and the interactions became substantial in brine, according to the results of electrophoretic mobility, surface wettability, and X-ray diffraction. Thus, contributing to the firm trapping of TRJS into the nanopore structure of the shale, triggering the formation of a tight hydrophobic membrane over the shale surface from the outward hemisphere. The addition of TRJS into WBDF had no deleterious effect on fluid properties after hot -treatment at 190 degrees C, implying that TRJS could find potential use

关键词： Janus nanosilica Thermo -responsive copolymer Anti-polyelectrolyte effect Shale stabilizer Inhibition Plugging Drilling fluid RHEOLOGICAL PROPERTIES QUANTITATIVE CHARACTERIZATION WELLBORE-STABILITY GRAFT-COPOLYMERS PLUGGING AGENT NANOPARTICLES Imbibition OIL MONTMORILLONITE ADSORPTION

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