Reduction of interfacial tension between residual crude oil and formation fluids in oil reservoirs is the key to enhanced oil recovery (EOR) by surfactant flooding. However, adsorption of injected surfactant on minerals in the oil-bearing rock matrix reduces the effectiveness of this method. The effects of surfactant adsorption and desorption in the rock matrix on the oil recovery ratio achieved by surfactant-EOR were assessed. Sodium dodecylbenzene sulfonate (SDBS), a common surfactant in EOR, was used with Berea sandstone samples (rock particles and cores) as adsorbent. Adsorption of SDBS in the samples increased with concentration, and the static saturated amount was 0.9 mg-SDBS/g-rock for 1.0 wt.% SDBS-water solution. If brine (1.0 wt.% salinity) was injected after saturated adsorption of SDBS in the core, 83% of adsorbed SDBS was desorbed into the brine (the reversibility effect). Ffield scale numerical simulations were conducted for a typical five spot model (area: 180 m x 180 m, thickness: 60 m) using core-flooding data to clarify the reversibility effect in oil reservoirs. By introducing the reversibility model into the simulations on of surfactant flooding injection of slugs of 0.1 PV and 0.3 PV into the initial reservoir, oil recovery factor showed differences of 2.3% and 2.9% compared to without the model, respectively. Injection of the surfactant solution after water-flooding caused a difference of only 0.4%.
All Science Journal Classification (ASJC) codes
- Fuel Technology
- Energy Engineering and Power Technology