Reservoir characterization and multiphase ﬂow property in the upper Minnelusa sandstone: Implication for geological carbon storage

Kou, Zuhao; Wang, Heng; Alvarado, Vladimir

doi:10.46690/ager.2022.06.10

Cited by 7 publications

(3 citation statements)

References 4 publications

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“…High concentrations of greenhouse gases cause weather patterns to change and the climate to warm. There are several ambiguities regarding the impact of humans on climate, and it is possible that other factors are accountable for the observed warming over the past century [1,2]. However, there is widespread agreement that both mitigating and preventative measures must be implemented simultaneously in order to obtain definitive solutions to this issue.…”

Section: Introductionmentioning

confidence: 99%

Optimizing CO2-Water Injection Ratio in Heterogeneous Reservoirs: Implications for CO2 Geo-Storage

Al-Khdheeawi

2024

Energies

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The performance of carbon geo-sequestration is influenced by several parameters, such as the heterogeneity of the reservoir, the characteristics of the caprock, the wettability of the rock, and the salinity of the aquifer brine. Although many characteristics, like the formation geology, are fixed and cannot be altered, it is feasible to choose and manipulate other parameters in order to design an optimized storage programme such as the implementation of CO2 injection techniques, including continuous injection or water alternating CO2, which can significantly increase storage capacity and guarantee secure containment. Although WAG (water-alternating-gas) technology has been widely applied in several industrial sectors such as enhanced oil recovery (EOR) and CO2 geo-sequestration, the impact of the CO2-to-water ratio on the performance of CO2 geo-sequestration in heterogeneous formations has not been investigated. In this study, we have constructed a 3D heterogeneous reservoir model to simulate the injection of water alternating gas in deep reservoirs. We have tested several CO2-water ratios, specifically the 2:1, 1:1, and 1:2 ratios. Additionally, we have estimated the capacity of CO2 trapping, as well as the mobility and migration of CO2. Our findings indicate that injecting a low ratio of CO2 to water (specifically 1:2) resulted in a much better performance compared to situations with no water injection and high CO2-water ratios. The residual and solubility trappings were notably increased by 11% and 19%, respectively, but the presence of free mobile CO2 was reduced by 27%. Therefore, in the reservoir under investigation, the lower CO2-water ratio is recommended due to its improvement in CO2 storage capacity and containment security.

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Section: Introductionmentioning

confidence: 99%

Optimizing CO2-Water Injection Ratio in Heterogeneous Reservoirs: Implications for CO2 Geo-Storage

Al-Khdheeawi

2024

Energies

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“…The injection of CO 2 into reservoirs for enhanced oil recovery while achieving partial CO 2 storage within the reservoir is termed CCUS for enhanced oil recovery (CCUS-EOR). This involves injecting CO 2 into oil and gas reservoirs to achieve tertiary recovery while simultaneously storing CO 2 . − Structure storage, capillary storage, dissolution storage, and mineralization storage are common methods for storing CO 2 , with mineralization storage being the safest type of storage. − In recent years, ultralow-permeability reservoirs have received considerable attention for CO 2 utilization projects. This is because ultralow-permeability reservoirs, with their low porosity and permeability characteristics, are suitable for CO 2 flooding.…”

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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“…As a result, it becomes difficult to effectively drive the oil within the matrix. Spontaneous imbibition behavior between the fracture–matrix system plays a critical role in the recovery of oil from the matrix in these types of reservoirs. − However, due to the combination of factors such as the narrow pore size, complex in pore-throat geometry, liquid phase boundary layer thickness, and uneven wetting characteristics of tight reservoirs, the spontaneous imbibition recovery of the rock matrix relying solely on capillary forces is only about 2.8–19.1%, leaving a significant amount of remaining oil that is difficult to exploit effectively. − How to improve the efficiency of reservoir imbibition recovery and increase the utilization of the remaining oil in the matrix has become the key to improving the recovery rate of this type of reservoir.…”

Section: Introductionmentioning

confidence: 99%

Insight into the Imbibition Behavior of Low-Frequency Artificial Vibration Stimulation in Tight Sandstone

Gu,

Qi,

Yang

et al. 2024

ACS Omega

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Reservoir characterization and multiphase ﬂow property in the upper Minnelusa sandstone: Implication for geological carbon storage

Cited by 7 publications

References 4 publications

Optimizing CO2-Water Injection Ratio in Heterogeneous Reservoirs: Implications for CO2 Geo-Storage

Optimizing CO2-Water Injection Ratio in Heterogeneous Reservoirs: Implications for CO2 Geo-Storage

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

Insight into the Imbibition Behavior of Low-Frequency Artificial Vibration Stimulation in Tight Sandstone

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