A simulation study to control the oil production rate of oil-rim reservoir under different injectivity scenarios

Davarpanah, Afshin; Mirshekari, Behnam

doi:10.1016/j.egyr.2018.10.011

Cited by 35 publications

(8 citation statements)

References 24 publications

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“…They concluded that solvent injection (solvent extraction and miscible injection) of different gases would be preferred as an efficient method in tight reservoirs [26]. Davarpanah and Mirshekari (2018) simulated one of the oil rim reservoirs by drilling new horizontal or vertical wells to improve the oil recovery factor. They concluded that drilling a new horizontal well regarding its greater contact with the reservoir would be an excellent choice to enhance the oil production rate [27].…”

Section: Introductionmentioning

confidence: 99%

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RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

Hu¹,

Peng

et al. 2020

Symmetry

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It is essential to have an adequate understanding of the fluid-structure in a porous medium since this gives direct information about the processes necessary to extract the liquid and the likely yield. The concept of symmetry is one of the petroleum engineering issues that has been used to provide an analytical analysis for modeling fluid dynamics through porous media, which can be beneficial to validate the experimental field data. Tight reservoirs regarding their unique reservoir characterization have always been considered as a challenging issue in the petroleum industries. In this paper, different injectivity scenarios which included chemical and thermal methods were taken into consideration to compare the efficiency of each method on the oil recovery enhancement. According to the results of this experiment, the recovery factor for foams and brine injection is about 80%, while it is relatively 66% and 58% for brine-carbon dioxide and brine-nitrogen, respectively. Consequently, foam injection after water flooding would be an effective method to produce more oil volumes in tight reservoirs. Moreover, KCl regarding its more considerable wettability changes has provided more oil production rather than other scenarios.

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Section: Introductionmentioning

confidence: 99%

“…Davarpanah and Mirshekari (2018) simulated one of the oil rim reservoirs by drilling new horizontal or vertical wells to improve the oil recovery factor. They concluded that drilling a new horizontal well regarding its greater contact with the reservoir would be an excellent choice to enhance the oil production rate [27].…”

Section: Introductionmentioning

confidence: 99%

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

Hu¹,

Peng

et al. 2020

Symmetry

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“…Selective water plugging not only involves the selective plugging of oil and water by the plugging agent, but also the selective entry of the plugging agent into the formation. Core simulation test results and coring well data show that the water-washed sections of oil layers with large permeability differences are all in high-permeability formations, while low-permeability formations have extremely poor water flooding effects and basically maintain the original oil saturation [26,27]. After long-term research experiments and field applications, many mature selective plugging agents have been studied.…”

Section: Water Plugging Mechanismmentioning

confidence: 99%

Selective Water Plugging Technology for Horizontal Well with Screen Completion

Deng

Jia²,

Liu

et al. 2021

Energies

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The SD107 gel system developed has good oil–water phase selective gelation and oil–water phase selective blocking properties. The static gel-forming experiment results showed that the gel water shutoff system formulated with oilfield reinjection water (oil content < 0.05%) has a viscosity of 200 mPa·s after gelation, and the gel water plugging system formulated with oilfield produced fluid (oil content ≥ 20.0%) had a viscosity of 26 mPa·s after gelation. Results of the core physical simulation experiment indicated that the enhanced recovery rate was the highest (34.6%) when the resistance ratio of the high-low permeability core was about 10.0 after plugging. As per the fluid volume (Q) of the oil well to be blocked, the maximum production pressure difference (∆P) was predicted, and on the basis of economic output, the resistance of the oil section, the resistance of the high water cut section, and the resistance of the water outlet section after plugging was used to calculate the plugging depth (re1, the limit water plugging radius), which offers a basis for the design of water plugging process parameters for horizontal wells. The field water plugging test results showed that after using this water plugging technology, the daily oil production increased from about 4 t/d to 20 t/d, the daily oil increase was 16 t/d, and the water cut decreased from 75% to about 25%. The water-blocking construction was a success.

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“…In petroleum engineering, the polymer is used as an additive in the petroleum reservoir to sweeping oil to increase oil recovery. Chemical flooding has subcategories such as polymer flooding, surfactant flooding, alkali/polymer flooding, and alkali/surfactant/polymer (ASP) flooding [25][26][27][28][29][30][31].…”

Section: Introductionmentioning

confidence: 99%

A Laboratory Approach to Measure Carbonate Rocks’ Adsorption Density by Surfactant and Polymer

Esfandyari

Moghani

Esmaeilzadeh

et al. 2021

Mathematical Problems in Engineering

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Chemical recovery techniques have always been considered as one of the efficient secondary and tertiary recovery methods to enhance the oil recovery factor. Regarding the diversity of reservoir heterogeneity and rock properties for each field, various chemical agents were taken into consideration to provide a feasible process that has the best agreement with the reservoir characterization. The objective of this paper is to investigate the considerable influence of a set of chemical agents and temperature impact on the surfactant adsorption density of carbonate rocks. According to the results of this experiment, higher temperatures provide lower surfactant adsorption density. The lowest adsorption carbonate rocks’ adsorption density had occurred at 80°C. Furthermore, it was witnessed that hydrolyzed polyacrylamide addition to the surfactant would cause a dramatic decrease in the adsorption density in comparison with the surfactant or polymer individually.

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A simulation study to control the oil production rate of oil-rim reservoir under different injectivity scenarios

Cited by 35 publications

References 24 publications

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

Selective Water Plugging Technology for Horizontal Well with Screen Completion

A Laboratory Approach to Measure Carbonate Rocks’ Adsorption Density by Surfactant and Polymer

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