Active substances such as asphaltene and resin in heavy
oil tend
to absorb on the oil–water interface. Thus, heavy oil and water
would easily emulsify into water-in-oil (W/O) emulsion under the shared
action of formation porous media. Emulsification of produced fluid
during heavy oil recovery is important for accurately calculating
the oil recovery. Studies on the properties of produced fluid can
effectively forecast the reservoir production dynamics. Therefore,
water/steam flooding experiments at different permeabilities, heavy
oil viscosity, and varying temperature were performed using long sand-packed
tubes. Accordingly, the flooding dynamics, emulsification states,
viscosity, droplet size distribution, and oil recovery deviation rate
(ORDR) were analyzed. The results show that produced oil is W/O emulsion
during water/steam flooding heavy oil. The water content of the produced
oil is mainly affected by temperature and can be as high as 30% in
the middle and late stages when the temperature is higher than 150
°C. Because the layered stacking structure of asphaltene and
resin weakens as temperature increases, they absorb more easily on
the oil–water interface. The water content of produced oil
the in middle stages is as high as 40% when the temperature is 250
°C, and the ORDR is as high as 50.28%. Furthermore, the water
droplet size increases with increase in permeability and temperature,
but it is not obviously affected by heavy oil viscosity. The evaporation
of light components is significant when the temperature is higher
than 150 °C. In particular, the percentages of asphaltene and
resin would increase with the evaporation of light components. Thus,
W/O emulsion would form more easily during water/steam flooding, and
hence, the efficient development of heavy oil would become difficult
in the middle and late stages.