Evaluation of void space of complicated potentially oil-bearing carbonate formation using X-ray tomography and electron microscopy methods

Galkin, Sergey; Martyushev, Dmitriy A.; Osovetsky, Boris; Казымов, К. П.; Song, Huaisen

doi:10.1016/j.egyr.2022.04.070

Cited by 28 publications

(8 citation statements)

References 25 publications

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“…As reported, the adsorption methane density could reach 2–7 times the bulk density, and the magnitude continues to rise by intensifying molecule–surface interactions. ,,, Hence, from theoretical perspective, ultra-tight formations possess the advantage over traditional geological sites on storing more CO 2 due to the presence of the adsorption phase. Currently, related research on CO 2 sequestration in ultra-tight formations is heat; however, microscopic characterization on CO 2 behavior inside nanopores, ,,− like quantified description of adsorption phase density and thickness as well as the magnitude on CO 2 storage quantity the nanopores could improve over macropores, remains a challenging knowledge gap. ,,− Effective evaluation on CO 2 sequestration in ultra-tight formations cannot be accomplished favorably until figuring out the nanoconfined CO 2 behavior and its comprehensive relevant sensitivity analysis.…”

Section: Introductionmentioning

confidence: 99%

CO₂ Storage Behavior in Nanopores: Implications for CO₂ Sequestration in Ultra-Tight Geological Formations

Huang

Lü

et al. 2023

Ind. Eng. Chem. Res.

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The fatal challenge that human beings are currently facing is global warming as a result of excessive CO 2 emission in the atmosphere. CO 2 sequestration, gaseous CO 2 injection into ultra-tight geological sites, is regarded as a promising approach to achieve CO 2 reduction substantially. In this work, emphasis is paid to CO 2 storage potential inside depleted shale or coal seam where the presence of nanopores is rich, and CO 2 molecules store in both bulk and adsorption states in nanopores. The microscopic characterization on CO 2 behavior in the nanospace, particularly quantitative description on the difference between CO 2 in the adsorption and bulk states, is still lacking. With the intention to shed light on nanoconfined CO 2 behavior, a simple yet robust theoretical work rooting in the chemical potential equilibrium of each CO 2 molecule in the entire system is implemented, and the shift of critical properties due to the nanoconfinement effect is coupled. Then, the CO 2 density can be described as a function of distance away from the nanopore wall; the CO 2 molecule is found to accumulate more densely while approaching the nanopore wall, suggesting an adsorption behavior from microscopic perspective. Results show that (a) the CO 2 adsorption-phase thickness is insensitive to nanopore size, ranging from 0.58 to 0.64 nm, and the ratio of adsorption density over bulk density could reach 1−2 orders of magnitude; (b) the CO 2 amount the 2 nm nanopore is able to store could reach over 7.2 times that in macropores, displaying the unique advantage of shale and coal formations on CO 2 sequestration over conventional oil/gas reservoirs; (c) increasing pressure can improve the total CO 2 geological sequestration performance, and the improvement of magnitude at the lowpressure range could be as great as 2.9 times that at a high-pressure range. This work provides a doable framework to investigate the CO 2 existence behavior in nanopores, enriching the theoretical basis to identify favorable geological sites for CO 2 sequestration.

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Section: Introductionmentioning

confidence: 99%

CO₂ Storage Behavior in Nanopores: Implications for CO₂ Sequestration in Ultra-Tight Geological Formations

Huang

Lü

et al. 2023

Ind. Eng. Chem. Res.

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“…Hence, it is considered to be a promising method to improve the oil displacement efficiency in the HONG reservoir of the Xinjiang oilfield, with a low matrix permeability of 58 mD, a porosity of 17.8%, and a low reservoir temperature of 42 °C. However, flue gas tends to flow through big channels existing in reservoir, significantly reducing the sweep efficiency and oil recovery [ 3 , 4 , 5 , 6 , 7 ].…”

Section: Introductionmentioning

confidence: 99%

Probing the Effect and Mechanism of Flue Gas on the Performance of Resorcinol/Hexamethylenetetramine-Based Polymer Gel in Flue Gas Flooding Reservoir

Qiao

Zhang

et al. 2022

Gels

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Polymer gel plugging is an effective method for gas mobility control in flue gas flooding reservoirs. However, the effect and mechanism of flue gas on the performance of polymer gels have rarely been reported. In this study, a polymer gel was prepared by cross-linking hydrolyzed polyacrylamide (HPAM) and resorcinol/ hexamethylenetetramine (HMTA) to illuminate the influencing mechanism of flue gas composition on gel. The gel rheological testing results showed that flue gas promoted gelation performance, whereas it seriously threatened gel long-term stability, especially at high pressure conditions. The influence of CO2 on the polymer gel had the characteristic of multiplicity. The hydrodynamic radius (Rh) and the initial viscosity of HPAM solution decreased in the presence of CO2. Nonetheless, the dissolved CO2 expedited the decomposition rate of HMTA into formaldehyde, which promoted the cross-linking process of the HPAM, leading to a shorter gelation time. Oxidation–reduction potential (ORP) tests and Fourier transform infrared spectroscopy (FTIR) analysis indicated that O2 played a leading role in the oxidative degradation of HPAM compared to CO2 and threatened the gel long-term stability at elevated gas pressures. To address the adverse effects caused by flue gas, it is highly desirable to develop polymer gels by adding oxygen scavengers or strengthening additives.

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“…In complex porous media, the pore geometry will affect the apparent wettability [15]. The reservoir rock is characterized mainly via X-ray tomography and scanning electron microscopy methods to obtain characteristics of the void space such as the facies, the pore throat size, and the structure heterogeneity, which has a significant impact on the multiphase flow within porous media [16][17][18][19]. To mobilize the residual oil in the void space, it is necessary to study the capillary effect based on the structure of the void space.…”

Section: Introductionmentioning

confidence: 99%

Investigation of the Effect of Capillary Barrier on Water–Oil Movement in Water Flooding

Zhou

et al. 2022

Applied Sciences

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Water flooding technology is widely used to improve oil recovery efficiency in oilfields. The capillary barrier effect induced by the complex pore structures in the reservoir rocks is a crucial reason for the trapping of a great deal of residual oil in oil reservoirs after water flooding. However, the formation condition along with the effect on the recovery rate of the capillary barrier under different wettability conditions should be investigated further. To bridge the gap between the microscopic mechanism of the capillary barrier effect and the macroscopic mechanism of oil displacement efficiency, a simple conceptual capillary model is constructed to obtain the formation conditions of the capillary barrier using the analysis method, and its influence on macroscopic oil displacement efficiency in the porous media model with an opening angle of 45° is systematically investigated in this study using direct numerical simulations (DNS) coupled with the volume of fluid method. The results showed that the capillary barrier effect plays a significant role in the formation of the residual oil in the reservoir rock and the contact angle and the opening angle are the primary factors for the formation of the capillary barrier. The capillary force is the driving force when the oil–water interface advances in the throat channel under water-wet conditions, while the capillary force hinders the movement of oil–water movement when the liquid flows out of the throat channel and when θ + β > 90o. Furthermore, the highest oil displacement efficiency is achieved at the intermediate capillary number and in the case that the minimum conditions of occurrence of the capillary barrier phenomenon are satisfied. This is of great significance for controlling the optimized contact angle to further enhance the oil recovery rate of current oil reservoirs using waterflooding technology.

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Evaluation of void space of complicated potentially oil-bearing carbonate formation using X-ray tomography and electron microscopy methods

Cited by 28 publications

References 25 publications

CO₂ Storage Behavior in Nanopores: Implications for CO₂ Sequestration in Ultra-Tight Geological Formations

CO₂ Storage Behavior in Nanopores: Implications for CO₂ Sequestration in Ultra-Tight Geological Formations

Probing the Effect and Mechanism of Flue Gas on the Performance of Resorcinol/Hexamethylenetetramine-Based Polymer Gel in Flue Gas Flooding Reservoir

Investigation of the Effect of Capillary Barrier on Water–Oil Movement in Water Flooding

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Evaluation of void space of complicated potentially oil-bearing carbonate formation using X-ray tomography and electron microscopy methods

Cited by 28 publications

References 25 publications

CO2 Storage Behavior in Nanopores: Implications for CO2 Sequestration in Ultra-Tight Geological Formations

CO2 Storage Behavior in Nanopores: Implications for CO2 Sequestration in Ultra-Tight Geological Formations

Probing the Effect and Mechanism of Flue Gas on the Performance of Resorcinol/Hexamethylenetetramine-Based Polymer Gel in Flue Gas Flooding Reservoir

Investigation of the Effect of Capillary Barrier on Water–Oil Movement in Water Flooding

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CO₂ Storage Behavior in Nanopores: Implications for CO₂ Sequestration in Ultra-Tight Geological Formations

CO₂ Storage Behavior in Nanopores: Implications for CO₂ Sequestration in Ultra-Tight Geological Formations