Assessing the effects of different gas types on stability of SiO2 nanoparticle foam for enhanced oil recovery purpose

Harati, Saeed; Bayat, Ali; Sarvestani, Mohammad Taghizadeh

doi:10.1016/j.molliq.2020.113521

Cited by 29 publications

(11 citation statements)

References 55 publications

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“…However, some experimental investigations have indicated generally superior performance of N 2 -based foams over those produced using CO 2 . 17 Additionally, N 2 promotes cost-effective and environment-friendly foaming applications along with better foam stability and noncomplex properties under harsh pressure and temperature conditions. 23 The physical properties of CO 2 are complex and vary significantly with the operating conditions.…”

Section: Introductionmentioning

confidence: 99%

“…The characteristics of foams are greatly influenced by reservoir conditions such as the pore pressure, overburden pressure, temperature, formation brine salinity, and rock wettability. As a matter of fact, most of the current studies report the foam behavior at lower temperatures than the reservoirs. − Very limited research was conducted under reservoir pressure and temperature. , However, these did not account for the effects of other key operating conditions, such as rock wettability, fracture–matrix interactions, formation salinity, and formation hardness. Therefore, insights into the foam performance under reservoir conditions are necessary to ensure its applicability and efficiency in real-world scenarios.…”

Section: Introductionmentioning

confidence: 99%

“…As mentioned above, the gas type is one of the critical factors that influence the characteristics of the generated foam. Most of the previous foam evaluation studies considered only two gases: nitrogen (N 2 ) ,, and carbon dioxide (CO 2 ). ,,− Both gases have been shown to be effective in generating foam in porous media using various foaming agents. However, some experimental investigations have indicated generally superior performance of N 2 -based foams over those produced using CO 2 .…”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Youssif,

Sharma,

Goual

et al. 2024

Energy Fuels

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Foam flooding in fractured tight oil reservoirs can enhance gas mobility and conformance control by diverting gas flow from high-permeability zones (fractures) to low-permeability ones (matrices). Several factors, including operating conditions, foam generation parameters, fluid injection schemes, and properties of injected and resident fluids, affect the fracture−matrix interactions. However, thus far, the literature provides a limited understanding of the effects of such factors on the fluid displacement mechanisms between matrices and fractures in propped fractured rocks under reservoir conditions. In this study, two different methane foam injection schemes were investigated for their impact on foamability and oil recovery from propped fractured oil-wet carbonate cores at 115 °C and 3500 psi: (1) foamalternating-gas injection (FAGI-D) and ( 2) foam-alternating-wet gas-alternating-gas injection (FAGI-W-D). The aqueous solutions consisted of high-salinity brine containing two foaming agents: surfactant A (anionic) and surfactant B (amphoteric). The macroscale foam flooding tests showed that the performance of foam in oil-wet porous media was significantly influenced by the number of cycles, foam slug size, total injection rate, and gas fraction. Surfactants A and B exhibited different foaming behaviors irrespective of the foam injection scheme at a fixed concentration (4000 ppm) and foam quality (85%). For surfactant A, a large foam slug size (i.e., six pore volumes) and a high injection rate were necessary to generate foam. In contrast, a lower slug size (i.e., three pore volumes) and a lower injection rate were sufficient for surfactant B. The latter also showed better tolerance toward oil and produced foam of good strength in oil-wet porous media. Therefore, the foam generated by surfactant B significantly reduced the gas mobility and enhanced the fluid displacement from the matrix, leading to higher oil recovery (20.61%) compared with its counterpart (12.96%). Interestingly, the performance of both surfactants was improved at a lower foam quality of 70% and resulted in better foamability, stability, and oil production from tight matrices. This behavior can be attributed to the high water content in the foam, which depleted the oil saturation inside the porous medium more efficiently, leading to increased foamability and higher foam stability. The results also demonstrated that a higher total injection rate of 3 cc/min supported the generation of gas bubbles and caused significant fracture−matrix interactions, diverting more gas from the fracture to the rock matrix.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Youssif,

Sharma,

Goual

et al. 2024

Energy Fuels

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“…Harati et al investigated the effects of different gas types including nitrogen, methane and carbon dioxide on foams which stabilized by SiO 2 nanoparticles and SDS. Results showed that the half time and oil recovery of methane, nitrogen and carbon dioxide foams at optimum nanoparticle concentrations are 1054 min with 25% R.F, 1720 min with 31% R.F and 62 min with 19% R.F, respectively (Harati et al 2020 ).…”

Section: Introductionmentioning

confidence: 99%

A review on application of nanoparticles for EOR purposes: history and current challenges

Iravani

Khalilnezhad

2023

J Petrol Explor Prod Technol

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Applications of nanotechnology in several fields of petroleum industry, e.g., refinery, drilling and enhanced oil recovery (EOR), have attracted a lot of attention, recently. This research investigates the applications of nanoparticles in EOR process. The potential of various nanoparticles, in hybrid and bare forms for altering the state of wettability, reducing the interfacial tension (IFT), changing the viscosity and activation of other EOR mechanisms are studied based on recent findings. Focusing on EOR, hybrid applications of nanoparticles with surfactants, polymers, low-salinity phases and foams are discussed and their synergistic effects are evaluated. Also, activated EOR mechanisms are defined and specified. Since the stabilization of nanofluids in harsh conditions of reservoir is vital for EOR applications, different methods for stabilizing nanofluids through EOR procedures are reviewed. Besides, a discussion on different functional groups of NPs is represented. Later, an economic model for evaluation of EOR process is examined and “Hotelling” method as an appropriate model for investigation of economic aspects of EOR process is introduced in detail. The findings of this study can lead to better understanding of fundamental basis about efficiency of nanoparticles in EOR process, activated EOR mechanisms during application of nanoparticles, selection of appropriate nanoparticles, the methods of stabilizing and economic evaluation for EOR process with respect to costs and outcomes.

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“…First, the solid nature of these NPs makes them less prone to harsh reservoir conditions . Second, the nanoscale size of these NPs makes them less susceptible to being mechanically entrapped or log-jammed in narrow pores or throats. − Third, NP adsorption at the water/gas (W/G) interface is considered irreversible due to its very high detachment energy compared to the surfactant that may be adsorbed and desorbed easily. − The irreversible adsorption of NPs on gas bubbles increases the maximum capillary pressure of bubble coalescence and delays liquid drainage. ,, Finally, NP arrangement at the lamella and plateau borders forms a barrier that alleviates lamella thinning and inter-bubble gas diffusion. , …”

Section: Introductionmentioning

confidence: 99%

Graphene Quantum Dot-Stabilized Foam for Enhanced Oil Recovery

Aboahmed,

Youssif,

Piri

et al. 2023

Ind. Eng. Chem. Res.

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Surfactant-based foams have often been proposed as mobility control agents in enhanced oil recovery (EOR); however, their lack of stability under reservoir conditions has limited their field applications. This study aims at enhancing the efficiency of foam EOR by using a nanofluid composed of cocamidopropyl hydroxysultaine amphoteric surfactant and graphene quantum dot (GQD) nanoparticles extracted from Wyoming coal. Macroscale foam flooding experiments were conducted under challenging reservoir conditions (3500 psi, 115 °C, and 200,000 ppm brine salinity) to represent unconventional oil formations such as Bakken. Foam was generated through the coinjection of nanofluid and methane in strongly oil-wet core samples of different lithology (Berea sandstone, Edward limestone, and Minnesota Northern Cream (MNC) limestone), and the impact of foam quality was investigated in each outcrop. The nanofluid resulted in improved bulk foam stability due to the generation of finely structured foam of a low average bubble size (277.83 μm) and thick lamellae (98.91 μm). The in situ formation of stable foam during the core flooding tests was reflected by an improved apparent viscosity that was greatly influenced by the petrophysical properties of the rocks (i.e., pore size, pore size distribution, permeability, and wettability condition). For instance, the process of bubble generation and collapse was significantly noticed in the Edward core sample as a result of its heterogeneous pore size and nonuniform pore size distribution compared to Berea and MNC core samples. On the other hand, foam texture and the number of generated lamellae films were controlled by the fraction of gas injected (foam quality). At 60% foam quality, the foam had a very fine texture, resulting in an increased pressure gradient across the core, reduced gas mobility, and therefore improved oil sweep efficiency by diverting more gas to inaccessible oil-filled pores. As a result, the incremental oil recovery due to foam flooding was 11.5, 16.2, and 7.3% for the Berea, Edward, and MNC core samples, respectively. This study provides an in-depth understanding of the mechanisms that contribute to foam EOR in various oil-wet porous media utilizing novel nanofluid formulations.

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Assessing the effects of different gas types on stability of SiO2 nanoparticle foam for enhanced oil recovery purpose

Cited by 29 publications

References 55 publications

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

A review on application of nanoparticles for EOR purposes: history and current challenges

Graphene Quantum Dot-Stabilized Foam for Enhanced Oil Recovery

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