A novel technique for quantifying the fate of CO2 injected in oil reservoir for geological utilization and storage

Hu, Ting; Wang, Yanfei; Xu, Tianfu; Tian, Hailong; Rui, Zhenhua; Zhao, Yang; Liu, Tingting

doi:10.1016/j.egyr.2023.04.364

“…The world is currently facing severe climate change, primarily driven by the massive emissions of greenhouse gases such as CO 2 , posing a significant threat to the Earth’s environment and human survival. − Despite this, world energy demand is still rising, and utilization of fossil fuel is still one of the most dominant energy sources . The Intergovernmental Panel on Climate Change (IPCC) in its Sixth Assessment Report emphasized the urgent need to substantially reduce CO 2 emissions to control global temperature rise .…”

Section: Introductionmentioning

confidence: 99%

Data-Driven Quantitative Study of Synergistic Effects on CCUS-EOR─A Case Study of Ultralow-Permeability Sandstone Reservoirs

Hu,

Chen,

Rui

et al. 2024

Energy Fuels

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CO 2 capture, utilization, and storage of CO 2 with enhanced oil recovery (CCUS-EOR) technology is an important method to achieve net-zero carbon goals. The two objectives of enhancing oil recovery and CO 2 storage exhibit both alignment and conflict, especially in the ultralow-permeability reservoir. However, current research often ignores the impact of reservoir heterogeneity, chemical reactions induced by CO 2, and the lack of quantitative characterization of synergies. This paper constructed a three-dimensional multiphase, multicomponent, thermal−hydraulic−chemical multifield coupled model for an actual well group. This paper thoroughly examines the mechanism of CO 2 storage in oil reservoirs and investigates the influence of geological and engineering parameters on CO 2 -enhanced oil recovery and storage by establishing a realistic CO 2 −water−oil−rock physicochemical reaction system. The gray correlation method was used to analyze the impact of various factors on the CO 2 oil displacement and storage, and the synergistic parameters were analyzed. The results show that reservoir pressure, WAG alternating cycles, and injection rate are synergistic parameters. In addition, the storage form of CO 2 is mainly structural storage, and mineralization storage can be ignored during the development of oil reservoirs. The amount of dissolved storage, however, gradually transforms into the amount of mineralized storage over time. During the 200 years of shut-in period, the amount of mineralized storage increased 13.6 times. It is also found that introducing hydrodynamic theory into the water−gas alternating injection process can effectively utilize the gravity of water and the buoyancy of CO 2 to increase the swept volume of CO 2 . When the depth of the gas and water injection points is small, the oil recovery and the CO 2 storage rate can be improved. The oil recovery of the final optimized plan is 40.5%, and the CO 2 storage rate is 64.5%. This study helps to better formulate development designs for ultralow-permeability reservoirs to achieve dual goals.

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“…The next stage of research mainly focuses on improving the recovery rate of unconventional oil and gas reservoirs with carbon dioxide. How to effectively inject CO 2 into shale or coal bed methane remains a key research and development direction for improving the recovery performance of such oil and gas reservoirs [9,10]. When the source and sink matching conditions are suitable, some CCUS projects in China have lower costs than the enhanced oil recovery (EOR) benefits, and have the potential for negative cost reduction [11,12].…”

Section: Introductionmentioning

confidence: 99%

Development and Applications of CO2-Responsive Gels in CO2 Flooding and Geological Storage

Ding,

Zhao,

Wen

et al. 2023

Gels

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Gel systems are widely used as plugging materials in the oil and gas industry. Gas channeling can be mitigated by reducing the heterogeneity of the formation and the mobility ratio of CO2 to crude oil. Cracks and other CO2 leaking pathways can be plugged during the geological storage of CO2 to increase the storage stability. By adding CO2-responsive groups to the classic polymer gel’s molecular chain, CO2 responsive gel is able to seal and recognize CO2 in the formation while maintaining the superior performance of traditional polymer gel. The application of CO2 responsive gels in oil and gas production is still in the stage of laboratory testing on the whole. To actually achieve the commercial application of CO2 responsive gels in the oil and gas industry, it is imperative to thoroughly understand the CO2 responsive mechanisms of the various types of CO2 responsive gels, as well as the advantages and drawbacks of the gels and the direction of future development prospects. This work provides an overview of the research progress and response mechanisms of various types of CO2 responsive groups and CO2 responsive gels. Studies of the CO2 responsive gel development, injectivity, and plugging performance are comprehensively reviewed and summarized. The shortcomings of the existing CO2 responsive gels system are discussed and the paths for future CO2 responsive gel development are suggested.

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Multiphase flow and reactive transport benchmark for radioactive waste disposal

Samper,

Mon,

Ahusborde

et al. 2024

Environ Earth Sci

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Compacted bentonite is part of the multi-barrier system of radioactive waste repositories. The assessment of the long-term performance of the barrier requires using reactive transport models. Here we present a multiphase flow and reactive transport benchmark for radioactive waste disposal. The numerical model deals with a 1D column of unsaturated bentonite through which water, dry air and $${\hbox {CO}_{2{(g)}}}$$ CO 2 ( g ) may flow and with the following reactions; aqueous complexation, calcite and gypsum dissolution/precipitation, cation exchange and gas dissolution. INVERSE-FADES-CORE V2, $$\hbox {DuMu}^X$$ DuMu X , TOUGHREACT and iCP were benchmarked with 6 test cases of increasing complexity, starting with conservative tracer transport under variably unsaturated conditions and ending with water flow, gas diffusion, minerals and cation exchange. The solutions of all codes exhibit similar trends. Small discrepancies are found in conservative tracer transport due to differences in hydrodynamic dispersion. Computed $${\hbox {CO}_{2{(g)}}}$$ CO 2 ( g ) pressures agree when a sufficiently refined grid is used. Small discrepancies in $${\hbox {CO}_{2{(g)}}}$$ CO 2 ( g ) and pH are found near the no-flow boundary at early times which vanish later. Discrepancies are due differences in the formulations used for gas flow at nearly water-saturated conditions. Computed $${\hbox {CO}_{2{(g)}}}$$ CO 2 ( g ) pressures show a fluctuation between $$10^{-4}$$ 10 - 4 and $$10^{-3}$$ 10 - 3 years which slows down the in-diffusion of $${\hbox {CO}_{2{(g)}}}$$ CO 2 ( g ) . This fluctuation is associated with chemical reactions involving $${\hbox {CO}_{2}}$$ CO 2 . There are discrepancies in solute concentrations due to differences in the Debye–Hückel (DH) formulation. They are overcome when all codes use the same DH formulation. The results of this benchmark will contribute to increase the confidence on multiphase reactive transport models for radioactive waste disposal.

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A novel technique for quantifying the fate of CO2 injected in oil reservoir for geological utilization and storage

Cited by 11 publications

References 30 publications

Data-Driven Quantitative Study of Synergistic Effects on CCUS-EOR─A Case Study of Ultralow-Permeability Sandstone Reservoirs

Data-Driven Quantitative Study of Synergistic Effects on CCUS-EOR─A Case Study of Ultralow-Permeability Sandstone Reservoirs

Development and Applications of CO2-Responsive Gels in CO2 Flooding and Geological Storage

Multiphase flow and reactive transport benchmark for radioactive waste disposal

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