New type plugging particle system with high temperature &amp; high salinity resistance

Zhao, Fu‐Gang; Li, Zihao; Wu, Jieheng; Hou, Jirui; Qu, Shiyuan

doi:10.1016/j.petrol.2017.03.024

Cited by 16 publications

(7 citation statements)

References 22 publications

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“…47−50 Therefore, it is necessary to develop a commercial product that can hold features of good injectivity, selective plugging, and high plugging intensity. Zhao et al 51 developed a new type of plugging materials coated with a layer of modified epoxide resin, combining the advantages of both organic and inorganic particles. These particles showed good performance in conformance control under a high-salinity and high-temperature environment.…”

Section: Introductionmentioning

confidence: 99%

Oil Displacement Performance Using Bilayer-Coating Microspheres

Yang

Cheng

Han³

et al. 2021

Ind. Eng. Chem. Res.

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We systematically investigate the plugging performance and oil-displacement efficiency of the novel bilayer-coating microspheres (BCMS) designed for in-depth conformance control within heterogeneous hydrocarbon reservoirs. Visualization experiments on various glass models, as well as one- and two-phase core floods have been carried out at reservoir temperature and fluid salinity. Our results demonstrate that the rigid outer layer of BCMS can successfully protect its adhesive inner coating, enabling BCMS to transport deeply into porous media. Increasing particle concentration yields higher collision probability, leading to the formation of particle assembly that could effectively block pore throats in high-permeability channels and achieve more oil recovery in the low-permeability zones. It is also shown that as the BCMS slug size increases, the oil recovery asymptotically reaches a maximum value. A larger slug size cannot highly enhance the plugging performance yet significantly increase the resistance factor. A smaller permeability ratio of parallel cores leads to a narrower difference between the fractional flow rates. When the permeability ratio is two or lower, the fractional flow rates of parallel cores are both around 50%, yielding the best oil-displacement efficiency. BCMS exhibits promising application potential in production enhancement under reservoir conditions.

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Section: Introductionmentioning

confidence: 99%

Oil Displacement Performance Using Bilayer-Coating Microspheres

Yang

Cheng

Han³

et al. 2021

Ind. Eng. Chem. Res.

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“…The enhanced oil recovery methods, such as low-salinity waterflooding, 27 polymer and surfactant flooding, 28 and alkaline surfactant–polymer flooding, 29 can be emphasized for this reservoir in the future development. For the preferential channel existing in the reservoir, the block technique should be applied, such as plugging particle 30 and preformed particle gel. 31 …”

Section: Resultsmentioning

confidence: 99%

Experimental and Statistical Investigation of Reservoir Properties with the Effect of Waterflooding Treatment

Tang

et al. 2020

ACS Omega

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An oilfield reservoir over long-term operation may have different petrophysical information, which has a significant impact on oilfield maintenance and finance. Successful oilfield enhanced oil recovery benefits a lot from identifying and analyzing the variations of the critical properties after long-term waterflooding treatments. Since the inspection wells drilled within different development periods contain the core samples that have the petrophysical information at that period, it is necessary to collect and test the samples from different periods to investigate the overall tendency of the petrophysical properties. The samples from four inspection wells, which were drilled in four stages since the very beginning of development, were subjected to in-laboratory core analysis methods to illustrate the variation of some critical parameters in the reservoir. The permeability and porosity variation are revealed clearly by the experimental results. The migration and dissolution of clay minerals play a crucial role in the variation of petrophysical information and pore structure. To quantify the variations above, we applied the multiple linear regression model into our investigation. The dependent variable and all of the predictors in the model come from the experimental results. The quantitative results show the closed correlation between different parameters in the formation. With the development stage moving forward, the weight coefficients for different predictors have multiple trends. The experimental and statistical approach provides a novel understanding of the reservoir properties with the effect of waterflooding treatment

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“…2021, 11, 3616 3 of 16 [41,42]. These MCL particles have been substantiated to be efficient in plugging high-permeability channels in porous media [43]. By adjusting the mixture ratio of MCL and fly ash, we can obtain TPF of various plugging rates.…”

Section: Microspherementioning

confidence: 99%

“…A series of MCL with a broad range of bonding temperatures can be produced by modifying the ratio of cardanol and phenolic resin as well as the reaction temperature [41,42]. These MCL particles have been substantiated to be efficient in plugging high-permeability channels in porous media [43]. By adjusting the mixture ratio of MCL and fly ash, we can obtain TPF of various plugging rates.…”

Section: Introductionmentioning

confidence: 99%

Profile Control Using Fly Ash Three-Phase Foam Assisted by Microspheres with an Adhesive Coating

et al. 2021

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Foam-assisted steam flooding is a promising technique to alleviate gas channeling and enhance sweep efficiency in heterogeneous heavy-oil reservoirs. However, long-term foam stabilization remains problematic at high temperatures. Three-phase foam (TPF), containing dispersed solid particles, has been proposed to improve foam stability under harsh reservoir conditions. We fabricated a novel TPF system by adding ultrafine fly ash particles, as well as high-temperature resistant microspheres with an adhesive coating layer. This work aims at assessing the ability of the generated TPF in controlling steam channeling and enhancing oil recovery. Static and core flood tests were performed to evaluate foam strength and stability. Our results suggested a stronger foamability at a lower consolidation agent concentration, while a longer half-life period of foam and settling time of solid particles at a larger consolidation agent concentration were observed. Bubbles suspended independently in the liquid phase, with sizes varying from 10 to 100 μm, smaller than that of the conventional foam, suggesting a significant enhancement of foam dispersity and stability. The plugging rate was close to 90% when the temperature was as high as 300 °C, demonstrating a well-accepted plugging effect under high temperatures. A larger pore volume injection of TPF yielded a higher EOR in parallel cores, which substantiated the effectiveness of the three-phase foam system in sealing high-permeability channels.

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New type plugging particle system with high temperature & high salinity resistance

Cited by 16 publications

References 22 publications

Oil Displacement Performance Using Bilayer-Coating Microspheres

Oil Displacement Performance Using Bilayer-Coating Microspheres

Experimental and Statistical Investigation of Reservoir Properties with the Effect of Waterflooding Treatment

Profile Control Using Fly Ash Three-Phase Foam Assisted by Microspheres with an Adhesive Coating

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