Open Access
Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles
Volume 76, 2021
Article Number 68
Number of page(s) 11
Published online 20 October 2021
  • Deng X., Tariq Z., Murtaza M., Patil S., Mahmoud M., Kamal M.S. (2021) Relative contribution of wettability alteration and interfacial tension reduction in EOR: A critical review, J. Mol. Liq. 325, 115175. [CrossRef] [Google Scholar]
  • Ding F., Gao M. (2021) Pore wettability for enhanced oil recovery, contaminant adsorption and oil/water separation: A review, Adv. Colloid Interface Sci. 289, 102377. [CrossRef] [Google Scholar]
  • Xiong Y., Winterfeld P., Wang C., Huang Z., Wu Y.-S. (2015) Effect of large capillary pressure on fluid flow and transport in stress-sensitive tight oil reservoirs, in: SPE Annual Technical Conference and Exhibition, 28 September 2015, Houston. [Google Scholar]
  • Hu D., Wyatt D., Chen C., Martysevich V. (2015) Correlating recovery efficiency to pore throat characteristics using digital rock analysis, in: SPE Digital Energy Conference and Exhibition, 3 March 2015, The Woodlands, Texas. [Google Scholar]
  • Delshad M., Bhuyan D., Pope G.A., Lake L.W. (1986) Effect of capillary number on the residual saturation of a three-phase micellar solution, in: SPE Enhanced Oil Recovery Symposium, 20 April 1986, Tulsa, Oklahoma. [Google Scholar]
  • Yuan C.-D., Pu W.-F., Wang X.-C., Sun L., Zhang Y.-C., Cheng S. (2015) Effects of interfacial tension, emulsification, and surfactant concentration on oil recovery in surfactant flooding process for high temperature and high salinity reservoirs, Energy Fuel 29, 10, 6165–6176. [CrossRef] [Google Scholar]
  • Jang J., Sun Z., Santamarina J.C. (2016) Capillary pressure across a pore throat in the presence of surfactants, Water Resour. Res. 52, 12, 9586–9599. [CrossRef] [Google Scholar]
  • Nguele R., Sasaki K., Sugai Y., Omondi B., Said Al-Salim H., Ueda R. (2016) Interactions between formation rock and petroleum fluids during microemulsion flooding and alteration of heavy oil recovery performance, Energy Fuel 31, 1, 255–270. [Google Scholar]
  • Mohamed A.I.A., Sultan A.S., Hussein I.A., Al-Muntasheri G.A. (2017) Influence of Surfactant Structure on the Stability of Water-in-Oil Emulsions under High-Temperature High-Salinity Conditions, J. Chem. 2017, 5471376. [Google Scholar]
  • Mandal A., Samanta A., Bera A., Ojha K. (2010) Role of oil-water emulsion in enhanced oil recovery, in: 2010 International Conference on Chemistry and Chemical Engineering, pp. 190–194. [Google Scholar]
  • Zhao H., Yang H., Kang X., Jiang H., Li M., Kang W., Sarsenbekuly B. (2020) Study on the types and formation mechanisms of residual oil after two surfactant imbibition, J. Pet. Sci. Eng. 195, 107904. [CrossRef] [Google Scholar]
  • Karnanda W., Benzagouta M.S., AlQuraishi A., Amro M.M. (2013) Effect of temperature, pressure, salinity, and surfactant concentration on IFT for surfactant flooding optimization, Arab. J. Geosci. 6, 9, 3535–3544. [CrossRef] [Google Scholar]
  • Kalam S., Abu-Khamsin S.A., Kamal M.S., Patil S. (2021) A review on surfactant retention on rocks: mechanisms, measurements, and influencing factors, Fuel 293, 120459. [CrossRef] [Google Scholar]
  • Ngo I., Sasaki K., Nguele R., Sugai Y. (2019) Improving surfactant EOR by water salinity alteration, ASEG Ext. Abstr. 2019, 1, 1–4. [Google Scholar]
  • Paternina C.A., Londoño A.K., Rondon M., Mercado R., Botett J. (2020) Influence of salinity and hardness on the static adsorption of an extended surfactant for an oil recovery purpose, J. Pet. Sci. Eng. 195, 107592. [CrossRef] [Google Scholar]
  • Ngo I., Srisuriyachai F., Sugai Y., Sasaki K. (2017) Study of heterogeneous reservoir effects on surfactant flooding in consideration of surfactant adsorption reversibility, in: SPWLA 23rd Formation Evaluation Symposium of Japan, Chiba, Japan, 11–12 October 2017. [Google Scholar]
  • Ngo I., Srisuriyachai F., Sasaki K., Sugai Y., Nguele R. (2019) Effects of Reversibility on Enhanced Oil Recovery Using Sodium Dodecylbenzene Sulfonate (SDBS), J. Japan Pet. Inst. 62, 4, 188–198. [CrossRef] [Google Scholar]
  • Islam M.S., Kleppe J., Rahman M.M., Abbasi F. (2018) An evaluation of IOR potential for the Norne Field’s E-segment using low salinity water-flooding: A case study, in: SPE Kingdom of Saudi Arabia Annual Technical Symposium and Exhibition. [Google Scholar]
  • Pollen E.N., Berg C.F. (2018) Experimental investigation of osmosis as a mechanism for low-salinity EOR, in: Abu Dhabi International Petroleum Exhibition & Conference, 2018. [Google Scholar]
  • Ain Binti Mohd Anuar N., Hussinyunan M., Sagala F., Katende A. (2017) The effect of WAG ratio and oil density on oil recovery by immiscible water alternating gas flooding citation the effect of WAG ratio and oil density on oil recovery by immiscible water alternating gas flooding, Am. J. Sci. Technol. 4, 5, 80–90. [Google Scholar]
  • Alagic E., Skauge A. (2010) Combined low salinity brine injection and surfactant flooding in mixed-wet sandstone cores, Energy Fuel 24, 6, 3551–3559. [CrossRef] [Google Scholar]
  • Sheng J.J. (2014) Critical review of low-salinity waterflooding, J. Pet. Sci. Eng. 120, 216–224. [Google Scholar]
  • Fattahi Mehraban M., Ayatollahi S., Sharifi M. (2019) Role of divalent ions, temperature, and crude oil during water injection into dolomitic carbonate oil reservoirs, Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles 74, 36. [Google Scholar]
  • Zaheri S.H., Khalili H., Sharifi M. (2020) Experimental investigation of water composition and salinity effect on the oil recovery in carbonate reservoirs, Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles 75, 21. [CrossRef] [Google Scholar]
  • Egbe D.I.O., Jahanbani Ghahfarokhi A., Nait Amar M., Torsæter O. (2021) Application of low-salinity waterflooding in carbonate cores: a geochemical modeling study, Nat. Resour. Res. 30, 1, 519–542. [CrossRef] [Google Scholar]
  • Song J., et al. (2020) Effect of salinity, Mg2+ and SO42− on “smart water”-induced carbonate wettability alteration in a model oil system, J. Colloid Interface Sci. 563, 145–155. [CrossRef] [Google Scholar]
  • Hosseinzade Khanamiri H., Baltzersen Enge I., Nourani M., Stensen J.Å., Torsæter O., Hadia N. (2016) EOR by low salinity water and surfactant at low concentration: impact of injection and in situ brine composition, Energy Fuel 30, 4, 2705–2713. [CrossRef] [Google Scholar]
  • Tavassoli S., Korrani A.K., Pope G.A., Sepehrnoori K. (2016) Low-salinity surfactant flooding – A multimechanistic enhanced-oil-recovery method, SPE J. 21, 03, 744–760. [Google Scholar]
  • Araz A., Kamyabi F. (2021) Experimental study of combined low salinity and surfactant flooding effect on oil recovery, Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles 76, 4. [Google Scholar]
  • Geffroy C., Cohen Stuart M.A., Wong K., Cabane B., Bergeron V. (2000) Adsorption of nonionic surfactants onto polystyrene: Kinetics and reversibility, Langmuir 16, 16, 6422–6430. [CrossRef] [Google Scholar]
  • Somasundaran P., Hanna H.S. (1985) Adsorption/desorption of sulfonate by reservoir rock minerals in solutions of varying sulfonate concentrations, Soc. Pet. Eng. J. 25, 03, 343–350. [CrossRef] [Google Scholar]
  • Chang Z., Chen X., Peng Y. (2018) The adsorption behavior of surfactants on mineral surfaces in the presence of electrolytes – A critical review, Miner. Eng. 121, 66–76. [CrossRef] [Google Scholar]
  • Ansah E.O., Nguele R., Sugai Y., Sasaki K. (2019) Predicting the antagonistic effect between albite-anorthite synergy and anhydrite on chemical enhanced oil recovery: effect of inorganic ions and scaling, J. Dispers. Sci. Technol. 42, 1, 21–32. [Google Scholar]
  • Kim Y., Kim C., Kim J., Kim Y., Lee J. (2020) Experimental investigation on the complex chemical reactions between clay minerals and brine in low salinity water-flooding, J. Ind. Eng. Chem. 89, 316–333. [CrossRef] [Google Scholar]
  • Bourbiaux B. (2020) Low salinity effects on oil recovery performance: underlying physical mechanisms and practical assessment, Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles 75, 37. [Google Scholar]
  • Tichelkamp T., Teigen E., Nourani M., Øye G. (2015) Systematic study of the effect of electrolyte composition on interfacial tensions between surfactant solutions and crude oils, Chem. Eng. Sci. 132, 244–249. [CrossRef] [Google Scholar]
  • Chai R., Liu Y., He Y., Cai M., Zhang J., Liu F., Xue L. (2021) Effects and mechanisms of acidic crude oil-aqueous solution interaction in low-salinity waterflooding, Energy Fuel 35, 12, 9860–9872. [CrossRef] [Google Scholar]
  • Ngo I., Nguele R., Sugai Y., Sasaki K. (2021) Investigation on surfactant desorption isotherm to enhance oil spontaneous recovery in a low permeability core, Int. J. Oil Gas Coal Technol. 28, 4, 421–441. [CrossRef] [Google Scholar]
  • Wu Y., Cheng L., Ma L., Huang S., Fang S., Killough J., Jia P., Wang S. (2021) A transient two-phase flow model for production prediction to tight gas wells with fracturing fluid-induced formation damage, J. Pet. Sci. Eng. 199, 108351. [CrossRef] [Google Scholar]
  • Austad T., RezaeiDoust A., Puntervold T. (2010) Chemical mechanism of low salinity water flooding in sandstone reservoirs, in: SPE Improved Oil Recovery Symposium, 24 April 2010, Tulsa, Oklahoma. [Google Scholar]
  • Sheng J.J. (2011) Modern chemical enhanced oil recovery: theory and practice, Elsevier, Burlington. [Google Scholar]
  • Katende A., Sagala F. (2019) A critical review of low salinity water flooding: Mechanism, laboratory and field application, J. Mol. Liq. 278, 627–649. [CrossRef] [Google Scholar]
  • Druetta P., Picchioni F. (2019) Surfactant flooding: The influence of the physical properties on the recovery efficiency, Petroleum 6, 149–162. [Google Scholar]

Current usage metrics show cumulative count of Article Views (full-text article views including HTML views, PDF and ePub downloads, according to the available data) and Abstracts Views on Vision4Press platform.

Data correspond to usage on the plateform after 2015. The current usage metrics is available 48-96 hours after online publication and is updated daily on week days.

Initial download of the metrics may take a while.