determining the optimum nanofluid for enhanced oil recovery...determining the optimum nanofluid for...
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Determining the optimum nanofluid for enhanced oil recovery
Presented by Katie Aurand [email protected]
NorTex Nano Summit Houston, Texas, USA
Oct. 13, 2014
Based on paper SCA2014-17 Authors: Katherine R. Aurand, Gunnar Sie Dahle, and Ole Torsæter
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Objective: Determine optimum silica nanoparticle
shape and size for EOR applications
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit 2
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Objective: Determine optimum silica nanoparticle
shape and size for EOR applications
Conclusion: • The largest nano-structured (fumed silica)
particles show best EOR potential
• Physical mechanisms currently dominate?
• Next step = particle modification and testing
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• Previous studies success
• Can use existing injection structures
• More environmentally friendly?
• Cost
Why nanofluids?
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Nanoparticle types
5
D50 = 106 nm D50 = 81 nm D50 = 86 nm
16 nm
7 nm 10 nm
Nano-structured particle (Fumed)
*Illustrations not to scale Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Nanoparticle types
6
D50 = 75 nm D50 = 18 nm
D50 = 8 nm
Nanoparticle (Colloidal)
*Illustrations not to scale Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Nanoparticle types
7
*Illustrations not to scale
Fumed-L
Fumed-M Fumed-S
Colloidal-L
Colloidal-S
Colloidal-M
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Nanofluid composition
Nanoparticles or nano-structured particles • D50 = 8 - 106 nm • > 98% SiO2 • Hydrophilic
Synthetic North Sea water • Salinity = 3.53% • DI water = base • Suite of salts Particles
suspended in aqueous solution
at 0.05 wt %
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Fluid properties
Nanofluids
Synthetic North Sea water
Crude oil Density = 0.87 g/cm3
Viscosity = 19.9 cP
9
Reservoir brine
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Procedures Core flooding
Interfacial tension (IFT) Contact angle
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Core flooding: Set-up
13 cm
3.8 cm
Berea sandstone core plug
> 93% Quartz
Kavg = 360 mD (285 – 438 mD) φavg = 18.6 %
PVavg = 24.8 mL
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Core flooding: Set-up
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Core flooding: Results
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Fumed-L
Fumed-M
Fumed-S
11.8% 5.7%
8.6%
Fumed-L 11.8% Fumed-M 8.6% Fumed-S 5.7%
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Core flooding: Results
14
Colloidal-L
Colloidal-M
Colloidal-S 2.4%
6.0%
3.5%
Colloidal-M 6.0% Colloidal-L 3.5% Colloidal-S 2.4%
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Core flooding: Results
15
Fumed-L
Fumed-M
Fumed-S
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Core flooding: Results
16
Colloidal-L
Colloidal-M
Colloidal-S
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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IFT and contact angle
17
Fluid IFT (mN/m) Contact angle NSB 16.4 27o
Fumed-L 12.6 22o
Fumed-M 12.0 19o
Fumed-S 14.9 23o
Colloidal-L 12.2 --- Colloidal-M 15.4 --- Colloidal-S 13.0 15o
Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit
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Discussion
• Largest nano-structured (fumed) particle (RF = 11.8%) = best
• Nano-structured particles (fumed) performed better than nanoparticles (colloidal)
• All nanofluids showed some EOR potential
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Discussion
• Contact angle & IFT: nanofluids reduce both, but no visible trends among the nanoparticle types and sizes
• Pressure increase throughout nano flooding stage (0.2 to 0.4 bar increase)
• Nanofluids with smaller total nanoparticle surface area performed better
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Discussion
• Mechanical recovery mechanisms dominate?
• Other factors, such as pH and pressure, could be contributing to the oil recovery
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Theory: Log-jamming
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Theory: Log-jamming
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• Modification of particle surface for salt stability
• Additional core flooding (esp. mass balance)
• Characterization of effluent
• Investigation of mechanisms
Future work
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Particle | Mechanisms | Effluent Modification Chacterization
Things to remember:
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Nano-EOR
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Thank you for your attention.
Questions?
25 Determining the optimum nanofluid for enhanced oil recovery Presented by Katie Aurand | Houston, Texas | Oct. 13, 2014 | NorTex Nano Summit