Enhanced bitumen extraction from oil sands using CO2-responsive surfactant combined with low-salinity brine: Toward cleaner production via CO2 utilization

Tosuai, Teerapat; Thanasaksukthawee, Vorasate; Lu, Yi; Akamine, Thakheru; Somprasong, Komsoon; Tangparitkul, Suparit

doi:10.1016/j.colsurfa.2023.131617

Cited by 6 publications

(2 citation statements)

References 73 publications

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“…It is important to note that the crude oil droplet remained almost spherical shape at the final stage of the dewetting dynamics, see Fig. 6, reflecting no domination of other forces (e.g., strong capillary and viscous) in action, as observed in other works [2,38]. Without detectable residual oil left on the substrate, the detaching droplet floated up gently.…”

Section: Dewetting Dynamics Performance In the Low-salinity Brinesmentioning

confidence: 66%

Crude oil-water interface partitioning of polyvinylpyrrolidone-coated silica nanoparticles in low-salinity brine

Tangparitkul

2022

Journal of Petroleum Science and Engineering

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Section: Dewetting Dynamics Performance In the Low-salinity Brinesmentioning

confidence: 66%

Crude oil-water interface partitioning of polyvinylpyrrolidone-coated silica nanoparticles in low-salinity brine

Tangparitkul

2022

Journal of Petroleum Science and Engineering

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“…Efficiently exploiting such unconventional, poor properties of reservoir characteristics (e.g., low porosity and low permeability , ) is normally realized with advanced production techniques deployed. Owing to the “tight” character of unconventional oils, the confined and connected pore-throat networks in reservoir formation are undoubtedly controlled by a capillarity, of which the reservoir fluids flow under a primary influence of capillary pressure acting upon due to the nature of the rock–fluid–fluid interactions. − Most efforts therefore focus on how to manipulate such a capillary pressure to improve the oil flow and lead to enhanced oil recovery, while the production technique of interest is the widely implemented “huff-n-puff” technique . The huff-n-puff technique is a process to stimulate tight reservoirs in cycles by using only a signal well for both fluid-injecting (hence “huff”) and oil-producing (hence “puff”) purposes.…”

Section: Introductionmentioning

confidence: 99%

Relative Permeability-Dictated Huff-n-Puff Technique in Tight Reservoirs: Suitability and Limitation toward Field Implementation

Tapanya,

Fongkham,

Ramadhan

et al. 2024

Energy Fuels

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Exploiting unconventional petroleum is needed in this era, and thus more enhancement has been introduced including chemical additives to manipulate the fluid flow characteristics. Although most of the examinations were at the laboratory scale, the scaling-up to reservoir applicability is in question and needs further studies. The current study examined laboratory-derived relative permeability (k r ) at various wettabilities and the oil−water interfacial tension on reservoir-scale numerical simulation, utilizing a huff-n-puff technique, aiming to emphasize suitability and limitations of k r . The simulated results emphasized the important character of k r , which dictates the oil recovery in tight reservoirs where the huff-n-puff technique is normally implemented. Although derived from laboratory tests, such a k r character has to be taken caution when considering EOR design in field deployment at the reservoir scale since there are suitability and limitations to be concerned for each k r character as well as the economic aspect. Not all reservoir parameters or producing factors could practically induce substantial changes in oil production; hence, further techno-economic study should be executed prior to implementation toward field implementation of tight reservoirs. Simulations of primary oil production agreed with those of the experiment, confirming the model validity. Following the secondary six-cycle huff-n-puff process also yielded the same trend of oil production performances, dictated by k r as a primary fluid flow characteristic. Four influencing factors of reservoir properties and producing design were further investigated for their sensitivity to the oil production performances. At various k r investigated in the current study, the porosity factor was distinctively found to have limited suitability to low values if high oil production is anticipated, owing to the nature of tight reservoirs pe se. On the contrary, reservoir permeability likely did not have much influence since more oil was produced with higher value of permeability, albeit no sensitivity at much higher values. The shut-in period for the huff-n-puff process was not sensitive to the oil production of all fluids. Interestingly, the critical water saturation where the water phase starts to flow (k rw > 0) had a strong influence on the oil production in two approaches, either demoting the oil production or having no contribution, depending on the k rw −S w character. Although derived from laboratory tests, such a k r character has to be taken caution when considering enhanced oil recovery design in reservoir-scale deployment since there are suitability and limitations to be concerned for each k r character.

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Anionic-nonionic and nonionic mixed surfactant systems for oil displacement: Impact of ethoxylate chain lengths on the synergistic effect

Wang,

Dai,

Liu

et al. 2023

Colloids and Surfaces A: Physicochemical and Engineering Aspect

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Enhanced bitumen extraction from oil sands using CO2-responsive surfactant combined with low-salinity brine: Toward cleaner production via CO2 utilization

Cited by 6 publications

References 73 publications

Crude oil-water interface partitioning of polyvinylpyrrolidone-coated silica nanoparticles in low-salinity brine

Crude oil-water interface partitioning of polyvinylpyrrolidone-coated silica nanoparticles in low-salinity brine

Relative Permeability-Dictated Huff-n-Puff Technique in Tight Reservoirs: Suitability and Limitation toward Field Implementation

Anionic-nonionic and nonionic mixed surfactant systems for oil displacement: Impact of ethoxylate chain lengths on the synergistic effect

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