12/25/2023 0 Comments Water no gravity london dispersioThe typical candidate gases for injection are dry or wet natural gases, Nitrogen, CO 2 and flue gas, a product from natural gas combustion from those gases, the CO 2 has been identified as the more efficient miscible agent based in its property to dissolve the oil. Once the MMP has been estimated by compositional reservoir simulation, the next step is to verify the model work with laboratory experiments applying methods such as slim tube tests, rising bubble, zero interfacial tension, these last two are more recent developments in determination of MMP. Usually it is important a survey of potential gas sources in the area. The determination of the MMP can be estimated with reasonable accuracy if there is available a compositional analysis of the reservoir oil and a representative PVT analysis, which can be used to build a representative one-dimension compositional simulations for various types of gases that might be available for injection. The recovery factor in those cases might had been in order of 60–70% if a miscible gas injection process would have been implemented at early stage of the field life cycle. This strategy might be considered reasonable and economic however the cases that we have seen have recoveries in the range of 35–45% of the original oil in place at the time when the GOR has increased to extremely high values that suggest the injected gas is being recycled. There have been cases where the implemented reservoir management strategy was focused to let the reservoir pressure to deplete below the bubble gas pressure to create a secondary gas cap to use the gas cap expansion as production mechanism. Historically it is more common to deal with immiscible gas injection projects, compared with the cases of miscible gas injection projects possibly because the opportunities for implementation of miscible displacement have not been identified in early stages, the high costs of compression to achieve miscibility and the access to the know-how. Some field cases of EOR Miscible Displacements injecting dry gas and CO 2 are also discussed in the context of EOR operations. This chapter discuss the concepts and elements that drive a Miscible Displacement, some practical strategies for project design, implementation and evaluation, field experiences from the Minimum Miscibility Pressure concept, application, and influence in field cases of Miscible Gas Injection projects performance, including natural gas, Dioxide Carbonate (CO 2), Nitrogen (N 2) and Flue. In some field cases, the MMP is determined in the mid or late field life when the reservoir pressure, temperature and fluids distribution might limit the time left to design and implement a miscible gas displacement in other, the operators possess the technology to design and implement Miscible Gas Displacement and the ability to articulate the project economy allowing time on decisions to implement, operate, and materialize the incremental recovery from a miscible displacement therefore, it is recommended to determine the miscibility pressure, as soon the field is identified as candidates for EOR. The difference of a miscible gas displacement with an immiscible displacement is of such importance because a miscible displacement could achieve a recovery factor as high as 75% to 90% of the contacted oil compared to 30–40% recovery factor for an immiscible displacement process. The Miscibility behaviour needs to be understood early after the reservoir discovery to establish if a miscible displacement is economically attractive. The Minimum Miscibility Displacement Pressure, and the strategies to maintain the reservoir pressure above the minimum miscibility pressure are the most important elements for a successful EOR Dry Gas, CO2, or N2 Miscible injection project.
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