بررسی آزمایشگاهی تأثیر انتشار بر توانایی تغییر ترشوندگی توسط فوم تثبیت شده با مخلوط سورفکتانت و نانوذره در یک مخزن ماسه سنگی

نوع مقاله : مقاله پژوهشی

نویسندگان

گروه مهندسی نفت، معدن و مواد، دانشکده عمران ومنابع زمین،دانشگاه آزاد اسلامی واحد تهران مرکزی، ایران

چکیده

فوم تثبیت شده با مخلوط نانوذره و سورفکتانت دارای توانایی بیشتری نسبت به سورفکتانت‌ها در جهت بهبود تحرک‌پذیری سیال تزریقی می‌باشد. تحرک‌پذیری فوم تزریقی تابعی از ویسکوزیته فوم و رفتار تراوایی نسبی فوم/نفت است که خود تابعی از ترشوندگی سنگ می‌باشد. مطالعات فراوانی روی بهبود تحرک پذیری از طریق افزایش ویسکوزیته ظاهری فوم انجام گرفته است. با این حال، پتانسیل محلول مولد فوم برای تغییر ترشوندگی کم‌تر مورد توجه قرار گرفته است. به این منظور، توانایی تغییر ترشوندگی شیشه نفت دوست توسط محلول مولد فوم از طریق آزمایش زاویه تماس از طریق دو دیدگاه نوآورانه رژیم انتشاری و همرفتی بررسی شد. در رژیم انتشاری، محلول‌های آب مقطر و نانوسیال (1/0 درصد وزنی از نانوذره کلسیم کربنات) قابلیت تغییر ترشوندگی شیشه را به سمت آب‌دوستی بیشتر نداشتند. محلول سورفکتانتی (CMC 1 از سورفکتانت SDS) تنها °5 از نفت دوستی شیشه کاهش داد. مخلوط سورفکتانت و نانوذره این تغییر ترشوندگی را به °16 رساند. در رژیم همرفتی، بر خلاف رژیم انتشاری، هم آب مقطر و هم نانوسیال دارای توانایی تغییر ترشوندگی شیشه به سمت آب‌دوستی بیشتر بودند. با این حال ترشوندگی تعادلی ایجاد شده برای آب مقطر (°76) آب‌دوست‌تر از نانوسیال (°76) بود. این رفتار به جذب نانوذره با بار مخالف روی سطح شیشه نسبت داده شد. محلول سورفکتانتی ترشوندگی اولیه را به °45 رساند. مخلوط سورفکتانت و نانوذره بهترین نتیجه را در این زمینه داشت و ترشوندگی اولیه را به °23 رساند. براساس آزمایش‌های کشش سطحی، رفتار برتر مخلوط سورفکتانت و نانوذره به جذب سطحی مولکول‌های سورفکتانت بر نانوذره و فعال سطحی شدن نانوذرات نسبت داده شد.
 

کلیدواژه‌ها


عنوان مقاله [English]

Experimental Investigation of the Effect of Diffusion of Surface-active Material on Enhanced Oil Recovery Using Surfactant-nanoparticle Stabilized Foam in Sandstone Reservoirs

نویسندگان [English]

  • Nika Ghasempour
  • Mahdi NazariSaram
  • Afshin Akbari Dehkharghani
Faculty of Civil and Earth Resources Engineering, Islamic Azad University, Centre Tehran Branch, Iran
چکیده [English]

Injection of nanoparticle-stabilized foam has been considered by the oil industry due to its high stability. In this study, the interaction between nanoparticles and surfactants as well as the hysteresis of the foam injection sequence is investigated. For this purpose, secondary and tertiary core injection experiments were performed on synthetic glass core to investigate the oil recovery behavior of foam stabilized with calcium carbonate nanoparticles and SDS surfactant in sandstone reservoirs. According to the results, the secondary oil recovery by foam stabilized with a mixture of 0.04 wt.% of surfactant and 0.1 wt.%  of nanoparticles is significantly higher than the foam stabilized with counterpart nanoparticle and surfactant. In all cases, tertiary oil recovery was significantly lower than the tertiary mode. This phenomenon was attributed to the diffusion regime governing tertiary recovery compared to the convective regime in the secondary injection. In order to prove this hypothesis, the aging process performed in the core injection experiments was repeated in the contact angle device. In the diffusion regime, the nano fluid could not change the wettability of the glass to more water-wetness. The surfactant solution reduced the glass oil-wetness by only 5 degrees. The mixture of surfactant and nanoparticles brought this change in wettability to 16. The Nano fluid, surfactant solution, and mixture of surfactant and nanoparticles brought the initial wettability of about 150˚ to 76˚, 45˚, and 23, respectively, which it confirms the higher rate of convective regime in the change of wettability. Based on surface tension experiments, the superior behavior of the surfactant and nanoparticle mixture was attributed to the adsorption of surfactant molecules on the nanoparticles and the surface activation of the nanoparticles.
 

کلیدواژه‌ها [English]

  • Foam Injection
  • Hysteresis
  • Nanoparticles
  • Surfactant
  • Diffusion Regime and Convection
[1]. Luo P, Zhang Y, Wang X, Huang S (2012) Propane-enriched CO2 immiscible flooding for improved heavy oil recovery, Energy and Fuels, 26, 4: 2124–2135. ##
[2]. Lake L W, Johns R, Rossen W R, Pope G A (2014) Fundamentals of enhanced oil recovery. ##
[3]. Anazadehsayed A, Rezaee N, Naser J, Nguyen A V (2018) A review of aqueous foam in microscale, Advances in Colloid and Interface Science, 256: 203–229. ##
[4]. Fu C, J Yu, Liu N (2018) Nanoparticle-stabilized CO2 foam for waterflooded residual oil recovery, Fuel, 234: 809–813. ##
[5]. Hurtado Y, Franco C A, Riazi M, Cortés F B (2020) Improving the stability of nitrogen foams using silica nanoparticles coated with polyethylene glycol, Journal of Molecular Liquids, 300: 112256. ##
[6]. Pickering S U (1907) Cxcvi.—emulsions, Journal of the Chemical Society, Transactions, 91, 2001–2021. ##
[7]. Worthen A J, Bagaria H G, Chen Y, Bryant S L, Huh C, Johnston K P (2013) Nanoparticle-stabilized carbon dioxide-in-water foams with fine texture, Journal of Colloid and Interface Science, 391, 142–151. ##
[8]. Aroonsri A, Worthen A J, Hariz T, Johnston K P, Huh C, Bryant S L (2013) Conditions for generating nanoparticle-stabilized CO2 foams in fracture and matrix flow, Presented at the SPE Annual Technical Conference and Exhibition. ##
[9]. Yekeen N, Kun T X, Al-Yaseri A, Sagala F, Idris A K (2021) Influence of critical parameters on nanoparticles-surfactant stabilized CO2 foam stability at sub-critical and supercritical conditions, Journal of Molecular Liquids, 338: 116658. ##
[10]. Chaturvedi K R, Narukulla R, Sharma T (2021) Effect of single-step silica nanoparticle on rheological characterization of surfactant-based CO2 foam for effective carbon utilization in subsurface applications, Journal of Molecular Liquids, 341: 16905. ##
[11]. Xu K, Zhu P, Colon T, Huh C, Balhoff M (2017) A microfluidic investigation of the synergistic effect of nanoparticles and surfactants in macro-emulsion-based enhanced oil recovery, SPE Journal, 22, 02: 459–469. ##
[12]. Ghosh P, Mohanty K K (2018) Novel application of cationic surfactants for foams with wettability alteration in oil-wet low-permeability carbonate rocks, SPE Journal, 23, 06: 2218–2231. ##
[13]. Yekeen N, Malik A A, Idris A K, Reepei N I, Ganie K (2020) Foaming properties, wettability alteration and interfacial tension reduction by saponin extracted from soapnut (Sapindus Mukorossi) at room and reservoir conditions, Journal of Petroleum Science and Engineering, 195: 107591. ##
[14]. Kumar A, Dixit C K (2017) Methods for characterization of nanoparticles, in Advances in nanomedicine for the delivery of therapeutic nucleic acids, Elsevier, 43–58. ##
[15]. Kumar N, Mandal A (2018) Surfactant stabilized oil-in-water nanoemulsion: stability, interfacial tension, and rheology study for enhanced oil recovery application, Energy and Fuels, 32, 6: 6452–6466. ##
[16]. Pal N, Kumar N, Saw R K, Mandal A (2019) Gemini surfactant/polymer/silica stabilized oil-in-water nanoemulsions: Design and physicochemical characterization for enhanced oil recovery, Journal of Petroleum Science and Engineering, 183, 106464. ##
[17]. Kuang W, Saraji S, Piri M (2018) A systematic experimental investigation on the synergistic effects of aqueous nanofluids on interfacial properties and their implications for enhanced oil recovery, Fuel, 220: 849–870. ##
[18]. Shabib-Asl A, Ayoub M A, Elraies K A (2019) A new hybrid technique using low salinity water injection and foam flooding for enhanced oil recovery in sandstone rock, Journal of Petroleum Science and Engineering, 174: 716–728. ##
[19]. Aziz R, Joekar-Niasar V, Martínez-Ferrer P J, Godinez-Brizuela O E, Theodoropoulos C, Mahani H (2019) Novel insights into pore-scale dynamics of wettability alteration during low salinity waterflooding, Scientific Reports, 9, 1: 1–13. ##
[20]. Aziz R, Niasar V, Erfani H, Martínez-Ferrer P J (2020) Impact of pore morphology on two-phase flow dynamics under wettability alteration, Fuel, 268: 117315. ##
[21]. Alizadeh M, Fatemi M (2020) Mechanistic study of the effects of dynamic fluid/fluid and fluid/rock interactions during immiscible displacement of oil in porous media by low salinity water: Direct numerical simulation, Journal of Molecular Liquids, 114544. ##
[22]. Alizadeh M, Fatemi M (2021) Pore-doublet computational fluid dynamic simulation of the effects of dynamic contact angle and interfacial tension alterations on the displacement mechanisms of oil by low salinity water, International Journal of Multiphase Flow, 143: 103771. ##
[23]. Alizadeh M, Fatemi M, Mousavi M (2021) Direct numerical simulation of the effects of fluid/fluid and fluid/rock interactions on the oil displacement by low salinity and high salinity water: pore-scale occupancy and displacement mechanisms, Journal of Petroleum Science and Engineering, 196: 107765. ##
[24]. Rashidi M, Kalantariasl A, Saboori R, Haghani A, Keshavarz A (2021) Performance of environmentally friendly water-based calcium carbonate nanofluid as enhanced recovery agent for sandstone oil reservoirs, Journal of Petroleum Science and Engineering, 196: 107644. ##
[25]. Selvan P, Jebakani D, Jeyasubramanian K, Jebaraj D J J (2022) Enhancement of thermal conductivity of water based individual and hybrid SiO2/Ag nanofluids with the usage of calcium carbonate nano particles as stabilizing agent, Journal of Molecular Liquids, 345: 117846. ##
[26]. Pourakaberian A, Mahani H, Niasar V (2021) The impact of the electrical behavior of oil-brine-rock interfaces on the ionic transport rate in a thin film, hydrodynamic pressure, and low salinity waterflooding effect, Colloids and Surfaces A: Physicochemical and Engineering Aspects, 620: 126543. ##
[27]. Farhadi H, Riahi S, Ayatollahi S, Ahmadi H (2016) Experimental study of nanoparticle-surfactant-stabilized CO2 foam: Stability and mobility control, Chemical Engineering Research and Design, 111: 449–460. ##
[28]. P Yazhgur, Noskov B A, Liggieri L, Lin S Y, Loglio G, Miller R, Ravera F (2013) Dynamic properties of mixed nanoparticle/surfactant adsorption layers, Soft Matter, 9, 12: 3305–3314. ##
[29]. Gu Y, Li D (2000) The ζ-potential of glass surface in contact with aqueous solutions, Journal of Colloid and Interface Science, 226, 2: 328–339. ##
[30]. Standnes D C, Austad T (2000) Wettability alteration in chalk: 1. Preparation of core material and oil properties, Journal of Petroleum Science and Engineering, 28, 3: 111–121. ##
[31]. Kumar K, Dao E K, Mohanty K K (2008) Atomic force microscopy study of wettability alteration by surfactants, SPE Journal Onepetro, 13, 02, 137–145. ##
[32]. Hou B, Wang Y, Cao X, Zhang J, Song X, Ding M, Chen W (2016) Surfactant-induced wettability alteration of oil-wet sandstone surface: mechanisms and its effect on oil recovery, Journal of Surfactants and Detergents, 19, 2: 315–324. ##