The method for selecting the chemical composition for surfactant-polymer flooding and field evaluation of the effectiveness of its application at the Kholmogorskoye field

UDK: 622.276.64
DOI: 10.24887/0028-2448-2022-9-100-105
Key words: surfactant-polymer flooding, chemical methods of enhanced oil recovery, residual oil saturation, single well chemical tracer test (SWCTT)
Authors: M.Yu. Bondar (Gazpromneft – Technological Partnership LLC, RF, Moscow), A.V. Osipov (Gazpromneft – Technological Partnership LLC, RF, Moscow), A.A. Groman (Gazpromneft – Technological Partnership LLC, RF, Moscow), I.N. Koltsov (Gazpromneft – Technological Partnership LLC, RF, Moscow), G.Yu. Shсherbakov (Gazpromneft – Technological Partnership LLC, RF, Moscow), O.V. Chebysheva (Gazpromneft – Technological Partnership LLC, RF, Moscow), S.V. Milchakov (Gazpromneft STC LLC, RF, Saint-Petersburg), А.S. Kosihin (Gazpromneft-Noyabrskneftegas JSC, RF, Noyabrsk)

The article considers enhanced oil recovery (EOR) methods in general and surfactant-polymer (SP) flooding in particular as a tertiary method for redevelopment of mature oil fields in Western Siberia, with potential to increase oil recovery to 60-70% original oil in place. The selection of effective surfactant blend and a polymer for SP flooding is a complex and multi-stage process. The surfactant and the polymer for chemical EOR were selecting during laboratory studies. Thermal stability, phase behavior, interfacial tension and rheology of SP formulation were investigated, and then a prospective chemical design was developed. Filtration experiments were carried out for optimization of slugs and concentrations. Then single well chemical tracer test (SWCTT) was used to evaluate residual oil saturation after water flooding and after implementation of chemical EOR in the near wellbore areas. The difference between the obtained values is a measure of the efficiency of SP flooding. Two SWCTT were conducted with same surfactant, but different design of slugs in order to prove technical and economic models of SP flooding. Oil saturation of sandstone reservoir after the injection of a surfactant-polymer solution was reduced about 10-11%; the increase in the oil recovery factor was about 18%. Temperature model of the bottomhole zone was created and verified. The model predicts that temperature of bottomhole zones essentially below that average in the reservoir. These results are important for interpretation of tracer test and surfactant efficiency. The tested surfactant showed an acceptable efficiency at under-optimum conditions, which is favorable for application of the SP formulation for neighboring field and layers with different reservoir temperatures, but similar water composition. In general, the results of the conducted field tests correlate with the results of the core experiments for the selected surfactant.



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