Assessment of polymer based carbonation in weak/strong alkaline media for energy production and carbon storage: An approach to address carbon emissions

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

doi:10.1016/j.jclepro.2021.129628

Cited by 13 publications

(2 citation statements)

References 34 publications

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“…Furthermore, tertiary recovery processes, particularly ASP processes, have been found to be effective chemical enhanced oil recovery (CEOR) processes in some reservoirs, such as the Daqing block 12 oil reservoir in China. , An ASP process combines the increased macroscopic swept efficiency of the polymer due to the reduced mobility of water injection, with improving microscopic displacement efficiency of surfactants (both additive and in situ saponification). For example, in an ASP solution, hydrolyzed polyacylamide can extend a swept volume by increasing the viscosity of the injection solution . Simultaneously, Na 2 CO 3 and sodium dodecyl sulfate (SDS) can reduce the O/W IFT, hence enhancing recovery efficiency .…”

Section: Introductionmentioning

confidence: 99%

“…For example, in an ASP solution, hydrolyzed polyacylamide can extend a swept volume by increasing the viscosity of the injection solution. 18 Simultaneously, Na 2 CO 3 and sodium dodecyl sulfate (SDS) can reduce the O/W IFT, hence enhancing recovery efficiency. 19 In China's Daqing oilfield, an ASP compound solution was first injected in March 1997, which achieved very promising results in terms of productivity compared to water flooding.…”

Section: Introductionmentioning

confidence: 99%

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Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

et al. 2022

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The alkaline–surfactant–polymer (ASP) enhanced oil recovery (EOR) is a promising tertiary oil recovery technique for maximizing oil production. However, strong alkaline (e.g., NaOH) or high concentration of an alkali may cause new problems, such as formation erosion, alkali deposition, and high production costs. In this study, a new EOR method was proposed by combining a traditional weak alkaline (Na2CO3) ASP flooding and nanotechnology. We investigated the synergistic effects of weak alkaline ASP chemicals and SiO2 nanoparticles on the EOR through comprehensive experiments. The efficacy of the mixtures was examined using a framework including interfacial tension and wettability characterizations, flow visualization experiments of emulsion, and oil recovery tests under reservoir temperature conditions. Moreover, the effects of weak alkaline ASP chemicals and SiO2 nanoparticles on interfacial properties and the EOR were carefully investigated by a comprehensive analysis. The experimental results show that the ASP + SiO2 nanoparticles mixture has a greater ability to reduce the interfacial tension (IFT) between oil and water as well as their contact angle, compared with a hydrolyzed polyacrylamide (HPAM)/ASP-only solution. The ASP + SiO2 nanoparticles mixture is better than the HPAM/ASP-only solution in profile control and displacement efficiency after water flooding. The SiO2 NPs/ASP mixture increases the oil recovery by 6.67% of original oil in place (OOIP), compared to the ASP-only solution. In visualization flooding experiments, the ASP + SiO2 nanoparticles mixture forms strong viscoelastic, thermodynamic, and kinetic stability of the droplets, thereby resulting in a larger sweep efficiency and better displacement efficiency by the stable blocking effects and strong scratch effect. It indicates that this new method can enhance oil recovery, have potential to reduce chemical agent cost, and avoid probable formation erosion and alkali deposition.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

et al. 2022

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Benchmarking the potential of a resistant green hydrocolloid for chemical enhanced oil recovery from sandstone reservoirs

Nowrouzi,

Mohammadi,

Khaksar Manshad

2024

Can J Chem Eng

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Polymer injection into oil reservoirs stands as a primary technique for enhanced oil recovery (EOR), employing either natural or synthetic polymers that dissolve in water. Proper performance in salinity and reservoir temperature creates a limitation to replace natural material with common chemicals and this has led researchers to try to identify new material for this application. Continuing the efforts and overcoming the challenge, this research introduces and examines a high‐performance natural polymer extracted from garden cress seeds for this application. Several experiments were planned and executed based on the existing EOR standards and literature. Comprehensive analyses and viscosity measurements were performed to identify the behaviour of solutions and the effects of concentration, shear rate, salinity, and temperature. Essential tests such as wettability and polymer adsorption were also done by contact angle measurement and flooding into a sandstone plug, respectively. The produced polymer was able to effectively maintain the viscosification properties at temperatures up to 95°C. Similarly, increasing the salinity up to 140,000 ppm did not affect its efficiency and the viscosity value remained in the useful range. The viscosity of the mature solutions at 35°C after 30 h at concentrations of 200, 400, 600, 800, 1000, and 1200 ppm was 8.61, 18.59, 31.27, 65.41, 95.38, and 149.75 mPa, respectively. At 1000 ppm and temperatures of 35, 55, 75, and 95°C, the viscosity was 95.38, 90.57, 86.73, and 84.72 mPa · s, respectively. At concentrations of 600, 800, and 1000 ppm, the wettability altered to intermediate‐wet, while at 1200 ppm, altered to water‐wet. Polymer injection caused an increase in recovery equal to 18.6%. The water cut increased with a little delay in the initial volumes of water injection at a high rate and reached its maximum. Then after the injection of 0.3 PV of polymer, there was a sharp and continuous drop until reaching 35% of the production fluid volume.

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CO2 EOR and injection process: Role of nanomaterials

Mahmud

Chaturvedi

Sharma

2022

Nanotechnology for CO2 Utilization in Oilfield Applications

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Assessment of polymer based carbonation in weak/strong alkaline media for energy production and carbon storage: An approach to address carbon emissions

Cited by 13 publications

References 34 publications

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Benchmarking the potential of a resistant green hydrocolloid for chemical enhanced oil recovery from sandstone reservoirs

CO2 EOR and injection process: Role of nanomaterials

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Assessment of polymer based carbonation in weak/strong alkaline media for energy production and carbon storage: An approach to address carbon emissions

Cited by 13 publications

References 34 publications

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO2 Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO2 Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Benchmarking the potential of a resistant green hydrocolloid for chemical enhanced oil recovery from sandstone reservoirs

CO2 EOR and injection process: Role of nanomaterials

Contact Info

Product

Resources

About

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery

Synergistic Effects of Weak Alkaline–Surfactant–Polymer and SiO₂ Nanoparticles Flooding on Enhanced Heavy Oil Recovery