Lithologic Reservoirs ›› 2021, Vol. 33 ›› Issue (3): 145-152.doi: 10.12108/yxyqc.20210315

• OIL AND GAS FIELD DEVELOPMENT • Previous Articles     Next Articles

Spontaneous imbibition characteristics of fracturing fluid in shale gas reservoir considering chemical osmotic pressure

XU Fei   

  1. Department of Engineering Technology Management, PetroChina Changqing Oilfield Company, Xi'an 7100161, China
  • Received:2020-07-27 Revised:2020-09-21 Published:2021-06-03

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Abstract: The chemical osmotic pressure caused by salinity difference between fracture and matrix has an important influence on shale fracturing fluid flowback and gas well productivity calculation. The driving force types of shale spontaneous imbibition were described by establishing an imbibition dynamic model considering chemical osmotic pressure. Taking Benxi Formation shale in Ordos Basin as the research object，the effects of clay minerals，salinity and surfactant on water saturation distribution curve were studied through the shale spontaneous imbibition NMR scanning experiment. The capillary pressure curve under the dual action of capillary pressure and chemical osmotic pressure was obtained with the water saturation distribution curve measured by experiment as the fitting target. The results show that with the increase of imbibition time，the water absorption of shale increases rapidly first and then gradually slows down，while the imbibition rate decreases rapidly. The higher the clay mineral contenf decreases rapidly. The higher the clay mint in shale and the greater the chemical potential difference between matrix and fracture，the stronger the imbibition driving force is，and the greater the imbibition front distance and water absorption capacity are. The surfactant can reduce the capillary pressure and cause the driving force to drop，leading to the significant weakening of imbibition effect. The modified capillary pressure curve was applied to production prediction of shale gas well，which greatly improves the calculation accuracy of the model. The results provide a method and basis for efficient development of shale gas reservoir in Ordos Basin.

Key words: shale gas, chemical osmotic pressure, spontaneous imbibition, flowback, salinity, Ordos Basin

CLC Number: 

  • TE357
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