Numerical simulation and optimization of CO2 enhanced gas recovery in homogeneous and vertical heterogeneous reservoir models

2021 ◽  
pp. 1-36
Author(s):  
Shuyang Liu ◽  
Ramesh Agarwal ◽  
Baojiang Sun
Keyword(s):  
Natural Gas ◽  
Injection Rate ◽  
Injection Time ◽  
Upward Migration ◽  
Enhanced Gas Recovery ◽  
Simulation And Optimization ◽  
Heterogeneous Reservoirs ◽  
Gas Recovery ◽  
Heterogeneous Reservoir ◽  
Optimal Injection

Abstract CO2 enhanced gas recovery (CO2-EGR) is a promising, environment-friendly technology with simultaneously sequestering CO2. The goals of this paper are to conduct simulations of CO2-EGR in both homogeneous and heterogeneous reservoirs to evaluate effects of gravity and reservoir heterogeneity, and to determine optimal CO2 injection time and injection rate for achieving better natural gas recovery by employing a genetic algorithm integrated with TOUGH2. The results show that gravity segregation retards upward migration of CO2 and promotes horizontal displacement efficiency, and the layers with low permeability in heterogeneous reservoir hinder the upward migration of CO2. The optimal injection time is determined as the depleted stage, and the corresponding injection rate is optimized. The optimal recovery factors are 62.83 % and 64.75 % in the homogeneous and heterogeneous reservoirs (804.76 m × 804.76 m × 45.72 m), enhancing production by 22.32 × 103 and 23.00 × 103 t of natural gas and storing 75.60 × 103 and 72.40 × 103 t CO2 with storage efficiencies of 70.55 % and 67.56 %, respectively. The cost/benefit analysis show that economic income of about 8.67 and 8.95 million USD can be obtained by CO2-EGR with optimized injection parameters respectively. This work could assist in determining optimal injection strategy and economic benefits for industrial scale gas reservoirs.

Modeling Condensate Banking Mitigation by Enhanced Gas Recovery Methods

2021 ◽  
Author(s):  
Adel Mohsin ◽  
Abdul Salam Abd ◽  
Ahmad Abushaikha
Keyword(s):  
Natural Gas ◽  
Finite Difference ◽  
Positive Impact ◽  
Enhanced Recovery ◽  
Gas Production ◽  
Dew Point ◽  
Productivity Index ◽  
Base Case ◽  
Enhanced Gas Recovery ◽  
Gas Recovery

Abstract Condensate banking in natural gas reservoirs can hinder the productivity of production wells dramatically due to the multiphase flow behaviour around the wellbore. This phenomenon takes place when the reservoir pressure drops below the dew point pressure. In this work, we model this occurrence and investigate how the injection of CO2 can enhance the well productivity using novel discretization and linearization schemes such as mimetic finite difference and operator-based linearization from an in-house built compositional reservoir simulator. The injection of CO2 as an enhanced recovery technique is chosen to assess its value as a potential remedy to reduce carbon emissions associated with natural gas production. First, we model a base case with a single producer where we show the deposition of condensate banking around the well and the decline of pressure and production with time. In another case, we inject CO2 into the reservoir as an enhanced gas recovery mechanism. In both cases, we use fully tensor permeability and unstructured tetrahedral grids using mimetic finite difference (MFD) method. The results of the simulation show that the gas and condensate production rates drop after a certain production plateau, specifically the drop in the condensate rate by up to 46%. The introduction of a CO2 injector yields a positive impact on the productivity and pressure decline of the well, delaying the plateau by up to 1.5 years. It also improves the productivity index by above 35% on both the gas and condensate performance, thus reducing production rate loss on both gas and condensate by over 8% and the pressure, while in terms of pressure and drawdown, an improvement of 2.9 to 19.6% is observed per year.

Research Progress of CO2 Sequestration with Enhanced Gas Recovery

2013 ◽  
Vol 807-809 ◽  
pp. 1075-1079
Author(s):  
Yi Zhang ◽  
Shu Yang Liu ◽  
Yong Chen Song ◽  
Wei Wei Jian ◽  
Duo Li ◽  
...  
Keyword(s):  
Experimental Data ◽  
Natural Gas ◽  
Large Scale ◽  
Economic Feasibility ◽  
Research Progress ◽  
Pilot Projects ◽  
Gas Field ◽  
Enhanced Gas Recovery ◽  
Gas Recovery ◽  
Feasibility Research

CO2Sequestration with Enhanced Gas Recovery (CSEGR) is one of the efficient and attractive scenarios to reduce CO2emission and accelerate gas field to produce more natural gas simultaneously. We review the correlational experiments, simulations and economic feasibility research about technical and economic problems of CSEGR. And the potential of natural gas increase production and CO2emission reduction in China by CSEGR is calculated. The pilot projects and simulation results show that CSEGR is technically feasible when suitable injection strategies and field management are implemented. However, economic feasibility is available only via policies of carbon credit, allowance and trade. Accurate experimental data would ensure the authenticity of key simulation parameters and reliability of simulations, but the existed experimental data is scarce. More experimental researches should be conducted to obtain a great quantity of accurate data which can make the simulation more close to the actual situation. Accordingly, the pilot projects and large-scale applications of CSEGR could be implemented successfully.

Dual-membrane natural gas pretreatment process as CO 2 source for enhanced gas recovery with synergy hydrocarbon recovery

2016 ◽  
Vol 34 ◽  
pp. 563-574 ◽  
Author(s):  
Bo Chen ◽  
Xiaobin Jiang ◽  
Wu Xiao ◽  
Yanan Dong ◽  
Issam El Hamouti ◽  
...  
Keyword(s):  
Natural Gas ◽  
Enhanced Gas Recovery ◽  
Hydrocarbon Recovery ◽  
Gas Recovery

scholarly journals Enhanced gas recovery by nitrogen injection: The effects of injection velocity during natural gas displacement in consolidated rocks

2020 ◽  
Vol 83 ◽  
pp. 103513
Author(s):  
Nuhu Mohammed ◽  
Abubakar J. Abbas ◽  
Godpower C. Enyi ◽  
Donatus E. Edem ◽  
Salihu M. Suleiman
Keyword(s):  
Natural Gas ◽  
Injection Velocity ◽  
Enhanced Gas Recovery ◽  
Gas Recovery ◽  
Nitrogen Injection

scholarly journals The Feasibility Appraisal for CO2 Enhanced Gas Recovery of Tight Gas Reservoir: Experimental Investigation and Numerical Model

Energies ◽  
2019 ◽  
Vol 12 (11) ◽  
pp. 2225
Author(s):  
Ying Jia ◽  
Yunqing Shi ◽  
Weiyi Pan ◽  
Lei Huang ◽  
Jin Yan ◽  
...  
Keyword(s):  
Natural Gas ◽  
Numerical Simulations ◽  
Supercritical Co2 ◽  
Tight Gas ◽  
Gas Reservoir ◽  
Enhanced Gas Recovery ◽  
Gas Recovery ◽  
Compositional Model ◽  
Co2 Diffusion ◽  
Tight Gas Reservoir

This paper proves the soundness of supercritical CO2 displacement for enhancing gas recovery of a tight gas reservoir via laboratory investigations and compositional modeling. First, a novel phase behavior experimental device with a screened supercritical CO2 dyeing agent were first presented to better understand the mixture characteristics between supercritical CO2 and natural gas. The mass transfer between two vapor phases was also measured. Then, based on experimental results, the compositional model considering the influence of CO2 diffusion on the gas recovery and critical property adjustment of supercritical CO2 was established. The miscibility process and mixing properties, such as density, viscosity, and the flowing velocity vector, of supercriticalCO2 and natural gas were visualized through a 3D display, which obtained a better understanding of the flooding mechanism of Enhanced Gas Recovery (EGR) via supercritical CO2. Finally, with experiments and numerical simulations, the main benefits of CO2 EGR were shown, which were partial miscibility between CO2 and natural gas, pressure maintenance, and CO2 displacement as a “gas cushion.” In general, experiments and numerical simulations demonstrate that CO2 EGR can be seen as a promising way of prolonging the productive life and enhancing recovery of tight gas reservoirs.

scholarly journals Experimental Study on Feasibility of Enhanced Gas Recovery through CO2 Flooding in Tight Sandstone Gas Reservoirs

Processes ◽  
2018 ◽  
Vol 6 (11) ◽  
pp. 214 ◽  
Author(s):  
Fengjiao Wang ◽  
Yikun Liu ◽  
Chaoyang Hu ◽  
Yongping Wang ◽  
Anqi Shen ◽  
...  
Keyword(s):  
Injection Rate ◽  
Co2 Flooding ◽  
Geological Storage ◽  
Co2 Geological Storage ◽  
Gas Reservoirs ◽  
Tight Sandstone ◽  
Gas Reservoir ◽  
Enhanced Gas Recovery ◽  
Gas Recovery ◽  
Dip Angle

The development of natural gas in tight sandstone gas reservoirs via CH4-CO2 replacement is promising for its advantages in enhanced gas recovery (EGR) and CO2 geologic sequestration. However, the degree of recovery and the influencing factors of CO2 flooding for enhanced gas recovery as well as the CO2 geological rate are not yet clear. In this study, the tight sandstone gas reservoir characteristics and the fluid properties of the Sulige Gasfield were chosen as the research platform. Tight sandstone gas long-core displacement experiments were performed to investigate (1) the extent to which CO2 injection enhanced gas recovery (CO2-EGR) and (2) the ability to achieve CO2 geological storage. Through modification of the injection rate, the water content of the core, and the formation dip angle, comparative studies were also carried out. The experimental results demonstrated that the gas recovery from CO2 flooding increased by 18.36% when compared to the depletion development method. At a lower injection rate, the diffusion of CO2 was dominant and the main seepage resistance was the viscous force, which resulted in an earlier CO2 breakthrough. The dissolution of CO2 in water postponed the breakthrough of CO2 while it was also favorable for improving the gas recovery and CO2 geological storage. However, the effects of these two factors were insignificant. A greater influence was observed from the presence of a dip angle in tight sandstone gas reservoirs. The effect of CO2 gravity separation and its higher viscosity were more conducive to stable displacement. Therefore, an additional gas recovery of 5% to 8% was obtained. Furthermore, the CO2 geological storage exceeded 60%. As a consequence, CO2-EGR was found to be feasible for a tight sandstone gas reservoir while also achieving the purpose of effective CO2 geological storage especially for a reservoir with a dip angle.

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