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

  • Fuwei YU ,
  • Hanqiao JIANG ,
  • Zhen FAN ,
  • Fei XU ,
  • Hang SU ,
  • Baoyang CHENG ,
  • Rengjing LIU ,
  • Junjian LI
Expand
  • 1. State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum, Beijing 102249, China
    2. SINOPEC International Petroleum Exploration & Production Corporation, Beijing 100029, China

Received date: 2018-07-14

  Revised date: 2019-07-05

  Online published: 2019-10-22

Supported by

Supported by China National Science and Technology Major Project(2017ZX05009-005-003)

Abstract

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 Winsor Ⅰ type surfactant solution (WⅠ solution) and the effect of NaCL concentration on phase change behavior of WI solution and imbibition in oil-wet porous media were investigated by microfluidic experiments in this study. The WⅠ solution and Winsor I type microemulsion are similar in wetting phase with stronger wettability than other phases. Two main mechanisms of WⅠ solution enhancing imbibitions recovery in oil wet porous media are the wetting phase drive and residual oil solubilization. Under the salinity condition of Winsor I type microemulsion, the NaCl concentration has strong impact on the imbibition mechanism of WI solution, 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 WI solution, the higher the NaCl concentration, the stronger the solubility of the WI solution to residual oil will be.

Cite this article

Fuwei YU , Hanqiao JIANG , Zhen FAN , Fei XU , Hang SU , Baoyang CHENG , Rengjing LIU , Junjian LI . Features and imbibition mechanisms of Winsor Ⅰ type surfactant solution in oil-wet porous media[J]. Petroleum Exploration and Development, 2019 , 46(5) : 1006 -1013 . DOI: 10.1016/S1876-3804(19)60257-0

References

[1] JIA Chengzao . Breakthrough and significance of unconventional oil and gas to classical petroleum geological theory. Petroleum Exploration and Development, 2017,44(1):1-11.
[2] YANG Hua, LIANG Xiaowei, NIU Xiaobing , et al. Geological conditions for continental tight oil formation and the main controlling factors for the enrichment: A case of Chang 7 Member, Triassic Yanchang Formation, Ordos Basin, NW China. Petroleum Exploration and Development, 2017,44(1):12-20.
[3] FANG Wenchao, JIANG Hanqiao, LI Junjian , et al. A numerical simulation model for multi-scale flow in tight oil reservoirs. Petroleum Exploration and Development, 2017,44(3):415-422.
[4] HU Suyun, ZHU Rukai, WU Songtao , et al. Profitable exploration and development of continental tight oil in China. Petroleum Exploration and Development, 2018,45(4):737-748.
[5] LIANG T B, LI Q G, LIANG X Y , et al. Evaluation of liquid nanofluid as fracturing fluid additive on enhanced oil recovery from low-permeability reservoirs. Journal of Petroleum Science and Engineering, 2018,168(9):390-399.
[6] FENG Cheng, SHI Yujiang, HAO Jianfei , et al. Nuclear magnetic resonance features of low-permeability reservoirs with complex wettability. Petroleum Exploration and Development, 2017,44(2):252-257.
[7] SHENG J J . What type of surfactants should be used to enhance spontaneous imbibition in shale and tight reservoirs?. Journal of Petroleum Science & Engineering, 2017,159:635-643.
[8] LIU He, JIN Xu, DING Bin . Application of nanotechnology in petroleum exploration and development. Petroleum Exploration and Development, 2016,43(6):1014-1021.
[9] PU W, WEI B, JIN F , et al. Experimental investigation of CO2, huff-n-puff process for enhancing oil recovery in tight reservoirs. Chemical Engineering Research & Design, 2016,111:269-276.
[10] YOU Q, WANG H, ZHANG Y , et al. Experimental study on spontaneous imbibition of recycled fracturing flow-back fluid to enhance oil recovery in low permeability sandstone reservoirs. Journal of Petroleum Science & Engineering, 2018,166:375-380.
[11] OLAJIRE A A . Review of ASP EOR (alkaline surfactant polymer enhanced oil recovery) technology in the petroleum industry: Prospects and challenges. Energy, 2014,77(C):963-982.
[12] LIANG T, ZHOU F, LU J . Evaluation of wettability alteration and IFT reduction on mitigating water blocking for low-permeability oil-wet rocks after hydraulic fracturing. Fuel, 2017,209(23):650-660.
[13] LIANG T, ACHOUR S H, LONGORIA R A , et al. Flow physics of how surfactants can reduce water blocking caused by hydraulic fracturing in low permeability reservoirs. Journal of Petroleum Science and Engineering, 2017,157:631-642.
[14] LI Y, POPE G A, LU J , et al. Scaling of low-interfacial-tension imbibition in oil-wet carbonates. SPE Journal, 2017,22(5):1349-1361.
[15] LI Y . Experimental investigation of imbibitions in oil-wet carbonates under low IFT conditions. Texas: University of Texas at Austin, 2016: 110-168.
[16] LIU S, ZHANG D L, YAN W , et al. Favorable attributes of alkali-surfactant-polymer flooding. SPE Journal, 2006,13(1):5-16.
[17] FLAATEN A, NGUYEN Q P, POPE G A , et al. A systematic laboratory approach to low-cost, high-performance chemical flooding. SPE Reservoir Evaluation & Engineering, 2009,12(5):713-723.
[18] HIRASAKI G J . Recent advances in surfactant EOR. SPE Journal, 2008,16(4):889-907.
[19] XU K, LIANG T, ZHU P , et al. A 2.5-D glass micromodel for investigation of multi-phase flow in porous media. Lab on A Chip, 2017,17(4):640-646.
[20] XU K, BONNECAZE R, BALHOFF M . Egalitarianism among bubbles in porous media: An Ostwald ripening derived anticoarsening phenomenon. Physical Review Letters, 2017,119(26):264502.
[21] TAGAVIFAR M, XU K, JANG S H , et al. Spontaneous and flow-driven interfacial phase change: Dynamics of microemulsion formation at the pore scale. Langmuir, 2017,33(45):13077-13086.
[22] HUH C . Equilibrium of a microemulsion that coexists with oil or brine. Society of Petroleum Engineers Journal, 1983,23(5):829-847.
[23] REED R L, HEALY R N . Contact angles for equilibrated microemulsion systems. SPE Journal, 1984,24(3):342-350.
Outlines

/