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Jia, Ying (Petroleum Exploration and Production Research Institute, SINOPEC) | Shi, Yunqing (Petroleum Exploration and Production Research Institute, SINOPEC) | Huang, Lei (Research Institute of Petroleum Exploration and Development, Petrochina) | Yan, Jin (Petroleum Exploration and Production Research Institute, SINOPEC) | Sun, Lei (SouthWest Petroleum University)
The YKL condensate gas reservoir is one of the biggest condensate gas reservoirs in China and has been developed more than 10years. At present, the combination of subdivision layer, production speed optimization and horizontal well drilling has been the key to economically unlocking the vast reserves of the YKL condensate gas. The primary recovery factor, however, remains rather low due to high capillary trapping and water invasion. While primary depletion could result in low gas recovery, CO2 flooding provides a promising option for increasing the recovery factor.
The objective of this work is to verify and evaluate the effect supercritical CO2 on enhancing gas recovery and analyze the feasibility of CO2 enhance gas recovery (CO2 EGR) of condensate gas reservoir.
Firstly, novel phase behavior experimental procedures and phase equilibrium evaluation methodology for gas-condensate phase system mixed with supercritical CO2 with high temperature were presented. A unique phase behavior phenomena was also reported. Then, CO2 floodingmechanism in condensate gas reservoir was analyzed and clarified based on experiments. Finally, a series of numerical simulation work were conducted as an effective and economical means to maximize natural gas recovery with the lowest CO2 breakthrough by varying strategies, including CO2 injection rate, injection composition, andinjection timing. Meanwhile the CO2 storage volumes of different strategies were calculated.
The results show that higher gas recovery factor can be achieved with CO2 injection through appearing interphase between two fluids, maintaining reservoir pressure, driving gas like "cushion" and controlling water invasion. All strategies have moderate to significant effects on gas production. The control of injection and production ratio needs to be balanced between pressure transient and CO2 breakthrough over the producer to obtain the maximum gas production. The varying injection pressure shows a positive effect of enhancing gas production. Numerical simulation indicated that the recovery of gas reservoir was improved by around 10 percent. The total CO2 storage would be around 30-40% HCPV.
The research showed that CO2 flooding presents a technically promising method for recovering the vast condensate gas while extensively reducing greenhouse gas emissions.
Mi, Lidong (Sinopec Petroleum Exploration and Production Research Institute) | Hu, Xiangyang (Sinopec Petroleum Exploration and Production Research Institute) | Jia, Ying (Sinopec Petroleum Exploration and Production Research Institute) | Liu, Qianjun (China University of Petroleum)
Multilayer commingled production is a common means for the development of multilayer tight gas reservoirs. The understanding of the production from each formation plays a significant role in the fine description of reservoir and remaining gas distribution, especially for the water-producing gas wells. In this paper, a dynamic method for production splitting of water-producing gas wells is introduced. First, a dynamic permeability calculation method is established based on the relative permeability curve and the water-gas ratio. Then, based on the catastrophe theory, a dynamic production splitting method considering the influence of various factors (reservoir characteristics, development characteristics and geological characteristics) is established. Finally, a dynamic production splitting system is developed of multi-layer combined production gas wells. The verification of production test data shows that the dynamic splitting method can better fit the production test results and accord with the actual production situation. This novel method can be used to split the production for the multilayer combined production well.
Noticeable progress in understanding the high efficiency of "foamy oil " in solution gas drive in heavy oil reservoirs has been made in recent years. However, "foamy oil " during CO 2 flooding was still a special and novel phenomenon when CO 2 flood asphatic oil. The basic mechanism and corresponding numerical equation of seepage flow of'foamy oil', in connection with CO 2 flooding, have not been reported. This paper presented the mechanism analysis and simulation study that addressed this issue. A new viewpoint of foamy oil during CO 2 flooding was proposed with contrasting the similarity of ''foamy oil"during CO 2 flooding front withthat in dissolved gas flooding. During CO 2 floodingthe''foamy oil" could form when CO 2 contacted with oil because precipitated asphaltene could facilitate bubble nucleation, decrease the critical super-saturation and help in maintaining the dispersed gas flow by suppressing bubble coalescence, whichsimilar to'foamy oil ' in depletion drive.Two main mechanisms were proposed. The first was enhancing oil recovery obviously by decreasing viscosity of crude oil, reducing interfacial tension, and swelling oil.