Features of creating hydrodynamic models of light oil deposits for simulating well treatments with carbon dioxide using the Huff and Puff technology

UDK: 622.276.6

DOI: 10.24887/0028-2448-2025-6-50-55

Key words: carbon dioxide (CO2) injection, Huff and Puff technology, factor analysis, additional oil production, enhanced oil recovery methods, compositional hydrodynamic model, intensification of inflow, reservoir hydrophobization, soak time

Authors: D.G. Afonin (Tyumen Petroleum Research Center LLC, RF, Tyumen; Industrial University of Tyumen, RF, Tyumen); I.V. Vydysh (Tyumen Petroleum Research Center LLC, RF, Tyumen); R.M. Galikeev (Tyumen Petroleum Research Center LLC, RF, Tyumen); S.V. Kostyuchenko (Tyumen Petroleum Research Center LLC, RF, Tyumen); A.A. Ruchkin (Tyumen Petroleum Research Center LLC, RF, Tyumen); N.A. Cheremisin (Tyumen Petroleum Research Center LLC, RF, Tyumen); G.A. Shchutskiy (RN-Yuganskneftegaz LLC, RF, Nefteyugansk)

The injection of carbon dioxide (CO2) into oil reservoirs is a well-known method of oil flow stimulation and enhanced oil recovery. The technology of CO2 injecting into producing wells, known as Huff and Puff (HnPCO2), has become a prevalent method of flow stimulation. This technology involves the injection of CO2 into an oil well, followed by a 10-50 days idle stage of the well. It can also be reapplied with a high degree of effectiveness after 8-12 months. A comprehensive analysis of the global experience of HnPCO2 technology implementation, along with findings from laboratory studies of cores and fluids, demonstrated its efficacy for both high and low permeability formations saturated with both heavy high-viscosity and light low-viscosity oils. The technological efficiency of CO2 injection into wells, as well as the contribution of the main factors to additional oil production, can be calculated using hydrodynamic models (HDM). However, direct reproduction of some significant physical effects in digital HDMs is not feasible. The necessary estimates of the contribution of such factors can be obtained from the analysis of the results of known field experience. This article delineates the principles of preparing digital models for calculating the technological efficiency of CO2 injection using HnPCO2 technology. The results of a model of CO2 injection in one of the oil fields of Western Siberia with low-permeability reservoir and low-viscosity oil are presented.

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