Potential Oil Recovery Enhancement by a Polymeric Nanogel Combined with Surfactant for Sandstone Reservoirs

Almahfood, Mustafa Mohammed; Bai, Baojun

doi:10.4043/30601-ms

Cited by 4 publications

(2 citation statements)

References 6 publications

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“…Consequently, due to prolonged and insufficient water circulation, the subsequent production phase after polymer flooding faces difficulties arising from the prevalence of dominant channels, rendering it more arduous to influence production solely through modifications at the injection phase. A consensus has been reached in the field of ASP flooding, recognizing the improvement in emulsification and recovery rates [41,42]. Therefore, incorporating a rational emulsification plugging approach in the design process of polymer flooding can effectively divert liquid flow and facilitate emulsification solubilization.…”

Section: Polysurfactant Oil Repellent Characteristicsmentioning

confidence: 99%

Study on the Structure–Activity Relationship and Oil Displacement Characteristics of the Polysurfactant Agent

He,

Yuan,

Gan

et al. 2024

Polymers

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This study examines a versatile polymer known as polysurfactant, which is synthesized by co-polymerizing flexible acrylamide and sodium acrylate hydrocarbon chain. The polymer serves as a backbone and possesses active functional groups. Notably, the polysurfactant exhibits superior plugging and flooding abilities compared to conventional polymers. The primary objective of this paper is to investigate the properties and oil displacement characteristics of the polysurfactant through indoor physical simulation experiments. The results demonstrate that the multi-branched structure of the polysurfactant enhances its ability to associate, leading to the formation of a unique spatial network structure. The inclusion of multi-branched structures notably amplifies the association effect. The critical concentration for the association is estimated to be around 800 mg/L, at which juncture the polysurfactant exhibits a viscosity retention rate surpassing 90% subsequent to shearing. Furthermore, this spatial network structure exhibits self-recovery capabilities after experiencing shear failure and displaying strong viscosity and shear resistance. In addition, the concentration of the polysurfactant can control the hydrodynamic feature size, which shows its adaptability in regulation and oil-repelling functions at reservoir permeabilities ranging from 500 to 2000 × 10−3 μm2 with resistance coefficients ranging from 108 to 320. During the microscopic oil displacement process, the polysurfactant exerts a significant impact on mobility control, while the elastic pull clearly demonstrates a commendable viscoelastic oil displacement effect. The polysurfactant exhibits a specific degree of emulsification capability towards crude oil, leading to the emulsion exhibiting typical pseudoplastic fluid characteristics. The utilization of emulsification transportation and emulsification blockage contributes to the enhancement of oil recovery. As a result, the polysurfactant exhibits multifaceted capabilities, encompassing profile control, flooding, and plugging, owing to its unique structural characteristics. Through the implementation of a field test focused on flooding in the Daqing Oilfield, a significant enhancement in the recovery rate of 10.85% is observed, accompanied by a favorable input–output ratio of 1:3.86, thereby generating significant economic advantages.

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Section: Polysurfactant Oil Repellent Characteristicsmentioning

confidence: 99%

Study on the Structure–Activity Relationship and Oil Displacement Characteristics of the Polysurfactant Agent

He,

Yuan,

Gan

et al. 2024

Polymers

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“…In contrast to conventional in-depth plugging agents such as preformed particle gels (PPG) and in situ gels, nanogels are characterized by low viscosity (Moraes et al 2011;Bai et al 2013). Also, nanogels can reduce the interfacial tension by adsorbing at the oil-water interface, which stabilizes oil-in-water emulsions, leading to improvement of the recovered oil from reservoirs (Geng et al 2018a;Almahfood et al 2020). Suleimanov and Veliyev (2017) showed that the oil recovery from a sandstone reservoir has increased by 6% after nanogel flooding, compared to gel treatment without nanosized particles.…”

Section: Introductionmentioning

confidence: 99%

Characterization and oil recovery enhancement by a polymeric nanogel combined with surfactant for sandstone reservoirs

Almahfood

Bai

2020

Pet. Sci.

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The characterization and enhanced oil recovery mechanisms of a nanosized polymeric cross-linked gel are presented herein. A negatively charged nanogel was synthesized using a typical free radical suspension polymerization process by employing 2-acrylamido 2-methyl propane sulfonic acid monomer. The synthesized nanogel showed a narrow size distribution with one peak pointing to a predominant homogeneous droplet size. The charged nanogels were also able to adsorb at the oil–water interfaces to reduce interfacial tension and stabilize oil-in-water emulsions, which ultimately improved the recovered oil from hydrocarbon reservoirs. In addition, a fixed concentration of negatively charged surfactant (sodium dodecyl sulfate or SDS) was combined with different concentrations of the nanogel. The effect of the nanogels combined with surfactant on sandstone core plugs was examined by running a series of core flooding experiments using multiple flow patterns. The results show that combining nanogel and SDS was able to reduce the interfacial tension to a value of 6 Nm/m. The core flooding experiments suggest the ability of the nanogel, both alone and combined with SDS, to improve the oil recovery by a factor of 15% after initial seawater flooding.

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Micellization Behavior and Thermodynamic Characteristics of Saponin and SDS: The Impact of Silica Nanoparticles for Subsurface Formation Interaction Studies

Muneer,

Alimkulov,

Eghtesadi

et al. 2024

ChemistrySelect

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This study investigates the temperature‐dependent micellization behaviors of saponin and sodium dodecyl sulfate (SDS) surfactants, which are both important for chemical enhanced oil recovery (CEOR). It also evaluates the effect of silica nanoparticles (SiO2) on these behaviors, given the growing interest in nanoparticle‐enhanced surfactants. The research focuses on the tunable properties of nanoparticle‐surfactant combinations. The structural differences between saponin and SDS were identified using FT‐IR and H‐NMR. The Du Noüy ring method was used to measure surface tension at various concentrations and temperatures (25–75 °C). FTIR analysis showed distinct differences between SDS and Saponin, associated with head group where there is hydroxyl groups in SDS solution. H‐NMR showed higher complexity of Saponin's structure, evidenced by its diverse sugar‐related proton peaks. Both SDS and Saponin reduce surface tension with temperature; SDS is more effective, lowering it to 42.1 mN/m versus 48.5 mN/m for Saponin. With SiO2, tensions drop to 39.2 mN/m for SDS and 45.5 mN/m for Saponin. Both surfactants maintain CMCs under reservoir temperature in the 0.05–0.1 wt % range. Saponin exhibited a more negative ΔG° and consistently negative ΔH°, indicating a thermodynamically favorable exothermic reaction. The novelty of this study lies in its focus on both anionic and nonionic surfactants under simulated reservoir conditions. The study focuses on the role of nanoparticles in enhancing surfactant stability and efficiency by addressing thermodynamic parameters.

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Potential Oil Recovery Enhancement by a Polymeric Nanogel Combined with Surfactant for Sandstone Reservoirs

Cited by 4 publications

References 6 publications

Study on the Structure–Activity Relationship and Oil Displacement Characteristics of the Polysurfactant Agent

Study on the Structure–Activity Relationship and Oil Displacement Characteristics of the Polysurfactant Agent

Characterization and oil recovery enhancement by a polymeric nanogel combined with surfactant for sandstone reservoirs

Micellization Behavior and Thermodynamic Characteristics of Saponin and SDS: The Impact of Silica Nanoparticles for Subsurface Formation Interaction Studies

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