A new approach for predicting oil recovery factor during immiscible CO2 flooding in sandstones using dimensionless numbers

Zivar, Davood; Pourafshary, Peyman

doi:10.1007/s13202-019-0630-0

Cited by 20 publications

(3 citation statements)

References 36 publications

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“…Akai et al 2015;Shi et al 2016;Sagir et al 2016;Phukan et al 2019;Zifar and Pourafshary 2019). These microbubbles with a dominant size of 10-50 µm were injected into SP#1 sandpack whose Microbubbles observation behavior a at an initial hour, b after 24 h, c microbubble size change for 24 h Microscopic images of microbubble at a an initial hour, b 6 h, c 12 h, d 18 h, e 24 h, f agglomerated microbubbles…”

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confidence: 99%

CO2 microbubble colloidal gas aphrons for EOR application: the generation using porous filter, diameter size analysis and gas blocking impact on sweep efficiency

Natawijaya

Sugai

Anggara

2019

J Petrol Explor Prod Technol

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The CO 2 is regarded to be an excellent solvent for miscible flooding. However, it is still facing a main problem which is the high mobility. Microbubbles with their unique characters offer some advantages for CO 2 EOR application. Different pore throat size filters were used to generate different dominant sizes of microbubbles that were injected into sandpacks under tertiary condition. Microscopic analysis was carried out to visualize the presence, stability and behavior of microbubbles inside the solution and porous media. The microbubbles with a dominant size of 10-50 µm showed additional 26.38% of oil recovery, showing their advantages over a larger dominant size of microbubbles up to 5.28% of oil recovery. The injection with larger microbubbles with a dominant size of 70-150 µm showed 27.5% of higher injection pressure than with a smaller dominant size of microbubbles, showing their advantage in gas blocking ability. In the heterogeneous porous media experiment, the recovery volume ratio between low-and high-permeability sandpacks was increased from 1:57 during water flooding to 1:4 during the CO 2 microbubble injection with 74.65% of additional recovery from a low-permeability zone, showing the microbubble gas blocking capability to change the flow pattern inside heterogeneous porous media.

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confidence: 99%

CO2 microbubble colloidal gas aphrons for EOR application: the generation using porous filter, diameter size analysis and gas blocking impact on sweep efficiency

Natawijaya

Sugai

Anggara

2019

J Petrol Explor Prod Technol

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“…For greater inclusivity, the conventional capillary number is modified for sandstone and chalk cores to consider the pore structure represented by capillary bundles, relating it to porosity and permeability [31]. Recently, several dimensionless numbers have been introduced to study CO 2 flooding concerning the displacement mechanisms [32]. The capillary number was found to be the most influential parameter in predicting oil recovery.…”

Section: Introductionmentioning

confidence: 99%

Performance Quantification of Enhanced Oil Recovery Methods in Fractured Reservoirs

2021

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The enhanced oil recovery mechanisms in fractured reservoirs are complex and not fully understood. It is technically challenging to quantify the related driving forces and their interaction in the matrix and fractures medium. Gravity and capillary forces play a leading role in the recovery process of fractured reservoirs. This study aims to quantify the performance of EOR methods in fractured reservoirs using dimensionless numbers. A systematic approach consisting of the design of experiments, simulations, and proxy-based optimization was used in this work. The effect of driving forces on oil recovery for water injection and several EOR processes such as gas injection, foam injection, water-alternating gas (WAG) injection, and foam-assisted water-alternating gas (FAWAG) injection was analyzed using dimensionless numbers and a surface response model. The results show that equilibrium between gravitational and viscous forces in fracture and capillary and gravity forces in matrix blocks determines oil recovery performance during EOR in fractured reservoirs. When capillary forces are dominant in gas injection, fluid exchange between fracture and matrix is low; consequently, the oil recovery is low. In foam-assisted water-alternating gas injection, gravity and capillary forces are in equilibrium conditions as several mechanisms are involved. The capillary forces dominate the water cycle, while gravitational forces govern the gas cycle due to the foam enhancement properties, which results in the highest oil recovery factor. Based on the performed sensitivity analysis of matrix–fracture interaction on the performance of the EOR processes, the foam and FAWAG injection methods were found to be more sensitive to permeability contrast, density, and matrix block highs than WAG injection.

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“…CO 2 injection method has been studied in various light and heavy oil reservoirs (Mangalsingh and Jagai 1996;Nobakht et al 2007;Ghedan 2009;Zekri et al 2013;Ma et al 2016;Seyyedsar et al 2016). Effective parameters of this process based on the laboratory investigation, field application or simulation are reported by some researchers (Trivedi and Babadagli 2009;Ghani et al 2015;Jaber and Awang 2017;Lashkarbolooki et al 2017;Zarghami et al 2017;Rostami et al 2018;Bhatti et al 2019;Biyanto et al 2019;Fakher et al 2019;Zivar and Pourafshary 2019).…”

Section: Introductionmentioning

confidence: 99%

Experimental studies of CO2-brine-rock interaction effects on permeability alteration during CO2-EOR

Okhovat

Hassani

Rostami

et al. 2020

J Petrol Explor Prod Technol

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Carbon dioxide (CO2) sequestration through CO2 enhanced oil recovery (EOR) in oil reservoirs is one way to reduce this gas in the atmosphere. Undesirable chemical reactions that occur during these operations can affect the reservoir structure and characteristics. In this study, the effect of CO2-water-rock interaction on the rock permeability alteration and final oil recovery has been evaluated experimentally during CO2 injection into a carbonate rock. The effect of flow rate, displacement type and pressure were investigated during CO2 EOR injection. Different scenarios of miscible/immiscible displacement, secondary/tertiary recovery has been evaluated for different levels of connate water salinity and injection rate. The results show that the severity of damage is directly related to the injection rate, however change in displacement type from miscible to immiscible reduce the intensity of chemical reactions in porous medium. Moreover, in the tertiary CO2 injection, the chemical reactions become more severe due to the higher water saturations. Interestingly, this growth in the level of chemical reactions has a negligible impact on permeability reduction, since the major volume of possible reactions occurs in coarse and high permeable pores. Results reveal that damage is more intense in the case of more saline water.

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A new approach for predicting oil recovery factor during immiscible CO2 flooding in sandstones using dimensionless numbers

Cited by 20 publications

References 36 publications

CO2 microbubble colloidal gas aphrons for EOR application: the generation using porous filter, diameter size analysis and gas blocking impact on sweep efficiency

CO2 microbubble colloidal gas aphrons for EOR application: the generation using porous filter, diameter size analysis and gas blocking impact on sweep efficiency

Performance Quantification of Enhanced Oil Recovery Methods in Fractured Reservoirs

Experimental studies of CO2-brine-rock interaction effects on permeability alteration during CO2-EOR

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