The article covers the issues of evaluation of the efficiency of innovative high-temperature reagent HIMMASTER 500 under steam-heat effect in different injection regimes. As a part of the work a complex of researches on physical modeling of oil displacement process at steam-heat influence was carried out with the use of a unique scientific unit for physical and chemical modeling of in-situ combustion and steam-gravity drainage. By means of physical modeling of steam-thermal influence on the core reservoir model the oil displacement coefficients were determined during the following experiments: at steam injection (basic experiment), at pre-injection of additive rim and further steam injection, at injection of additive solution and steam. On the basis of the obtained data the optimal mode of steam injection with the developed additive was selected and the efficiency of this agent was proved. In addition it was established that the reagent helps to reduce the contact angle of wettability, increasing the water wettability of the rock. It was also determined that the reagent has high thermal stability at temperatures up to 220 °C, and provides an increase in the oil displacement coefficient by 4,7 % when injected together with steam. At the same time, the need to optimize the conditions for using the reagent during its separate injection was revealed, which requires further study. The effectiveness of the chemical reagent was proven, the optimal steam injection mode with the innovative additive was selected, and its applicability for increasing oil recovery at fields developed using thermal methods was substantiated.
References
1. Nikolaeva M.V., Atlasov R.A., Review of technologies for the development of heavy oils and natural bitumens in conditions of permafrost (In Russ.), Neftegazovoye Delo, 2015, V. 13 4, pp. 126–131, EDN: VTKTBJ
2. Derevyanko V.K. et al., Selection of optimal EOR for extra-heavy crude oil displacement from low-permeability reservoirs, AIP Conference Proceedings, 2023,
V. 2929, no. 1, DOI: https://doi.org/10.1063/5.0180385
3. Zeidani K., Gupta S.C., Surfactant-steam process: an innovative enhanced heavy oil recovery method for thermal applications, SPE-165545-MS, 2013,
DOI: https://doi.org/10.2118/165545-MS
4. Derevyanko V.K. et al., Feasibility of foam-enhanced water-gas flooding for a low-permeability high-fractured carbonate reservoir. screening of foaming agent and flooding simulation, SPE-217637-MS, 2023, DOI: https://doi.org/10.2118/217637-MS
5. Al-Khafaji A.H. et al., Steam surfactant systems at reservoir conditions, SPE-10777-MS, 1982, DOI: https://doi.org/10.2118/10777-MS
6. Suncor Energy. Application for Chemical (Alkali and/or surfactant) Pad 22 co-injection test, Suncor Mackay River oil sands project, Energy Resources Conservative Board application, 2011, no. 1690728.
7. Connacher Oil and Gas Limited. Application to amend approval №. 10587E to add surfactant to the steam injected into well pairs 102W-04 & 102W-05 at Connacher’s Pod One SAGD facility, Energy Resources Conservative Board application, 2011, no. 1707322.
8. Duy Nguyen et al., Adhesion and surface energy of shale rocks, Colloids and Surfaces A: Physicochemical and Engineering Aspects, 2017, V. 520, pp. 712–721,
DOI: https://doi.org/10.1016/j.colsurfa.2017.02.029
9. Minkhanov I.F. et al., Experimental study on the improving the efficiency of oil displacement by co-using of the steam-solvent catalyst (In Russ.), Neftyanoe khozyaystvo = Oil Industry Journal, 2021, no. 6, pp. 54–57, DOI: https://doi.org/10.24887/0028-2448-2021-6-54-57
10. Minkhanov I.F. et al., The influence of the content of clay minerals on the efficiency of steam treatment injection for the bitumen oils recovery, SOCAR Proceedings, 2021, Special Issue 2, pp. 65–75, DOI: https://doi.org/10.5510/OGP2021SI200569
Юбилей Великой Победы
В юбилейном 2025 году подготовлены: - специальная подборка статей журнала, посвященных подвигу нефтяников в годы Великой Отечественной войны; - списки авторов публикаций журнала - участников боев и участников трудового фронта. |
