Experimental investigation on effect of reservoir conditions on stability and rheology of carbon dioxide foams of nonionic surfactant and polymer: Implications of carbon geo-storage

Pandey, Anjanay; Sinha, Asha; Chaturvedi, Krishna Raghav; Sharma, Tushar

doi:10.1016/j.energy.2021.121445

Cited by 63 publications

(29 citation statements)

References 83 publications

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“…The CMC for the non-ionic surfactant has been determined via electrical conductivity, and these observations have been provided in a separate study. 42 The non-ionic surfactant was chosen based on the research finding in the literature where non-ionic surfactant (as compared to the cationic surfactant) showed lower adsorption on negatively charged rock surface. 45 In addition, non-ionic surfactants have lower ecological toxicity and less dangerous end-products, as compared to other conventional surfactants used in oilfield.…”

Section: Resultsmentioning

confidence: 99%

“…The foam used in this study had a viscosity of 0.62 Pa•s at 1 s −1 due to the presence of 4000 ppm polymer, which is similar to that observed for CO 2 foams in previous work. 42 3.2. Effect of Cushion Gas Slug Size.…”

Section: Resultsmentioning

confidence: 99%

“…Also, while foam stability is positively impacted by pressure, the increasing temperature tends to reduce this nature. 42 3.3. Effect of the Gas Injection Rate on Hydrogen Storage.…”

Section: Resultsmentioning

confidence: 99%

“…A detailed overview of the foaming process and its stability has been reported separately in previous work. 42 Compressed air at 6 bar (maximum rating of the compressor, Elephant India) was introduced in the pot while an impeller (attached to an electric motor) rotation was maintained at 2000 rpm for 0.5 h to ensure the agitation inside the stirring pot. Following this, foam was directly introduced in fabricated sand-pack with inlet volume being measured by the volume of liquid displaced at the outlet of sand-pack.…”

Section: Introductionmentioning

confidence: 99%

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Air Foams for Mobility Control and Subsurface Storage of Hydrogen in Porous Media: An Experimental Study

et al. 2022

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This study initially explores and reports the feasibility of surfactant foams to increase the efficacy of hydrogen storage in porous media. This is an essential field of study, which aims to tackle a primary concern of the future hydrogen-based economy-hydrogen storage, which is essential for the supply of energy during periods of intermittent supply. For this, storage of hydrogen in porous media is explored wherein non-uniform front advance and superior gas mobility reduce storage efficacy. To mitigate this concern, the foam was prepared using compressed air and a non-ionic surfactant, Triton X-100, in a guar gum solution of 4000 ppm. A fabricated sand-pack, prepared from the sand of size 100−180 μm, was used as porous media, in which hydrogen storage was evaluated for a fixed flow rate of 30 mL/h as a function of varying slug sizes. The inclusion of foam as mobility control fluid massively increased hydrogen storage by a factor of 1.5−2.7, with slug size 0.5 PV being the most desirable. Enhanced hydrogen storage was obtained when a slug of 0.3 PV or greater was used. Altering the gas flow rate from 30 to 60 mL/h reduced hydrogen storage by 34%. The presence of crude oil reduces foam stability, and the injection and storage of hydrogen gas in depleted oilfields having high volume of crude oil is thus not recommended. This study promotes the use of surfactant foams for subsurface storage of hydrogen in sandstone media by controlling the mobility of injected gas.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

“…Also, while foam stability is positively impacted by pressure, the increasing temperature tends to reduce this nature. 42 3.3. Effect of the Gas Injection Rate on Hydrogen Storage.…”

Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Air Foams for Mobility Control and Subsurface Storage of Hydrogen in Porous Media: An Experimental Study

et al. 2022

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“…Synthetic polymers and biopolymers have shown sterling properties for stabilizing foam [ 88 , 89 ]. Wang et al [ 90 ] examined the influence of HPAM on alpha olefin sulfonate (AOS) foam stability.…”

Section: Binary Combination Of Polymers and Other Additives For Eormentioning

confidence: 99%

Application of Polymers for Chemical Enhanced Oil Recovery: A Review

et al. 2022

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Polymers play a significant role in enhanced oil recovery (EOR) due to their viscoelastic properties and macromolecular structure. Herein, the mechanisms of the application of polymeric materials for enhanced oil recovery are elucidated. Subsequently, the polymer types used for EOR, namely synthetic polymers and natural polymers (biopolymers), and their properties are discussed. Moreover, the numerous applications for EOR such as polymer flooding, polymer foam flooding, alkali–polymer flooding, surfactant–polymer flooding, alkali–surfactant–polymer flooding, and polymeric nanofluid flooding are appraised and evaluated. Most of the polymers exhibit pseudoplastic behavior in the presence of shear forces. The biopolymers exhibit better salt tolerance and thermal stability but are susceptible to plugging and biodegradation. As for associative synthetic polyacrylamide, several complexities are involved in unlocking its full potential. Hence, hydrolyzed polyacrylamide remains the most coveted polymer for field application of polymer floods. Finally, alkali–surfactant–polymer flooding shows good efficiency at pilot and field scales, while a recently devised polymeric nanofluid shows good potential for field application of polymer flooding for EOR.

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Evaluation of foaming agents for high‐temperature, high‐pressure, and high‐salinity reservoirs based on a new foam evaluator

Li,

Ge,

Shi

et al. 2024

J Surfact & Detergents

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In this study, a novel high‐temperature and high‐pressure foam evaluator with variable diameters inner cell and cylinder flip function was designed on our own, which can solve the problems such as difficulties in foam generation and inaccurate determination of various foam parameters by the same type of instruments, through which the foaming performance of more than 10 betaine surfactants was evaluated. The results show that: (1) the higher the pressure, the higher the foaming rate of the foaming agent and the more stable the foam, but the foam stability of the foamers at low and high pressures, and low and high temperatures do not correspond exactly, and the foaming agent used needs to be screened under simulated reservoir conditions. (2) The comprehensive foaming performance of different types of foamers with different molecular structures found that hydroxy sulfobetaine with longer carbon chains has a relatively better foaming performance. Therefore, for the reservoir conditions of temperature 130°C, pressure 30 MPa, and salinity 22 × 104 mg/L, hydroxy sulfobetaine, which does not contain an amide group in the molecule, can be considered preferentially as a foaming agent. The results can guide the selection of foaming agents for high‐temperature and high‐salinity reservoirs.

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Experimental investigation on effect of reservoir conditions on stability and rheology of carbon dioxide foams of nonionic surfactant and polymer: Implications of carbon geo-storage

Cited by 63 publications

References 83 publications

Air Foams for Mobility Control and Subsurface Storage of Hydrogen in Porous Media: An Experimental Study

Air Foams for Mobility Control and Subsurface Storage of Hydrogen in Porous Media: An Experimental Study

Application of Polymers for Chemical Enhanced Oil Recovery: A Review

Evaluation of foaming agents for high‐temperature, high‐pressure, and high‐salinity reservoirs based on a new foam evaluator

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