title: Comparison of oil removal in surfactant alternating gas with water alternating gas, water flooding and gas flooding in secondary oil recovery process.
abstract: Growing oil prices coupled with large amounts of residual oil after operating common enhanced oil recovery methods has made using methods with higher operational cost economically feasible. Nitrogen is one of the gases used in both miscible and immiscible gas injection process in oil reservoir. In heterogeneous formations gas tends to breakthrough early in production wells due to overriding, fingering and channeling. Surfactant alternating gas (SAG) injection is one of the methods commonly used to decrease this problem. Foam which is formed on the contact of nitrogen and surfactant increases viscosity of injected gas. This increases the oil-gas contact and sweep efficiency, although adsorption of surfactant on rock surface can causes difficulties and increases costs of process. Many parameters must be considered in design of SAG process. One of the most important parameters is SAG ratio that should be in optimum value to improve the flooding efficiency. In this study, initially the concentration of surfactant was optimized due to minimization of adsorption on rock surface which results in lower cost of surfactant. So, different sodium dodecyl sulfate (SDS) concentrations of 100, 500, 1000, 2000, 3000 and 4000 ppm were used to obtain the optimum concentration at 70 °C and 144.74×105Pa. A simple, clean and relatively fast spectrophotometric method was used for determination of surfactant which is based on the formation of an ion-pair. Then the effect of surfactant to gas volume ratio on oil recovery in secondary oil recovery process during execution of immiscible surfactant alternating gas injection was examined experimentally. The experiments were performed with sand pack under certain temperature, pressure and constant rate. Experiments were performed with surfactant to gas ratio of 1:1, 1:2, 1:3, 2:1 and 3:1 and 1.2 pore volume injected. Then, comparisons were made between obtained results (SAG) with water flooding, gas flooding and water alternating gas (WAG) processes. This study shows that using the concentration of 1500 ppm of surfactant solution is practical and economical. Results also show that the SAG ratio of 1:1 with 0.2 cm3/min at temperature and pressure of 70 °C and 144.74×105Pa, has the maximum oil removal efficiency. In this SAG ratio, stable foam was formed and viscous fingering delayed in comparison to other ratios. Finally, the results demonstrated that SAG injection has higher oil recovery in comparison to other displacement methods (water flooding, gas flooding and WAG).
authors.affiliation: Chemical Engineering Department, Sahand University of Technology, Tabriz, Iran.
authors.forename: Mehdi Mohammad
authors.initials: MM
authors.lastname: Salehi
authors.affiliation: Reservoir Studies and Field Development Department, Research Institute of Petroleum Industry, Tehran, Iran.
authors.forename: Mohammad Amin
authors.initials: MA
authors.lastname: Safarzadeh
authors.affiliation: Chemical Engineering Department, Sahand University of Technology, Tabriz, Iran.
authors.forename: Eghbal
authors.initials: E
authors.lastname: Sahraei
authors.affiliation: Chemical Engineering Department, Sahand University of Technology, Tabriz, Iran.
authors.forename: Seyyed Alireza Tabatabaei
authors.initials: SA
authors.lastname: Nejad
keywords: API, American Petroleum Institute; BPR, back pressure regulator; EV, volumetric sweep efficiency; MMP, minimum miscible pressure; OOIP, original oil in place; PV, pore volume; S.S, surfactant solution; SAG, surfactant alternating gas; SDS, sodium dodecyl sulfate; SO, Safranin-O; WAG, water alternating gas; foam; recovery; sand pack; spectrophotometer; surfactant alternating gas