Eyring-Theory-Based Model To Estimate Crude Oil Viscosity at Reservoir Conditions†

2009 ◽  
Vol 23 (1) ◽  
pp. 464-470 ◽  
Author(s):  
Ricardo Macías-Salinas ◽  
Cecilia Durán-Valencia ◽  
Simón López-Ramírez ◽  
Christian Bouchot
Keyword(s):  
Crude Oil ◽  
Oil Viscosity ◽  
Reservoir Conditions ◽  
Eyring Theory

Experimental measurement and compositional modeling of crude oil viscosity at reservoir conditions

2020 ◽  
Vol 109 ◽  
pp. 35-50
Author(s):  
Mohsen Talebkeikhah ◽  
Menad Nait Amar ◽  
Ali Naseri ◽  
Mohammad Humand ◽  
Abdolhossein Hemmati-Sarapardeh ◽  
...  
Keyword(s):  
Crude Oil ◽  
Experimental Measurement ◽  
Oil Viscosity ◽  
Compositional Modeling ◽  
Reservoir Conditions

scholarly journals Improvement of Steam Injection Processes Through Nanotechnology: An Approach through in Situ Upgrading and Foam Injection

Energies ◽  
2019 ◽  
Vol 12 (24) ◽  
pp. 4633 ◽  
Author(s):  
Oscar E. Medina ◽  
Yira Hurtado ◽  
Cristina Caro-Velez ◽  
Farid B. Cortés ◽  
Masoud Riazi ◽  
...  
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
High Performance ◽  
Steam Injection ◽  
American Petroleum Institute ◽  
Oil Viscosity ◽  
Nitrogen Injection ◽  
Injection Process ◽  
Reservoir Conditions

This study aims to evaluate a high-performance nanocatalyst for upgrading of extra-heavy crude oil recovery and at the same time evaluate the capacity of foams generated with a nanofluid to improve the sweeping efficiency through a continuous steam injection process at reservoir conditions. CeO2±δ nanoparticles functionalized with mass fractions of 0.89% and 1.1% of NiO and PdO, respectively, were employed to assist the technology and achieve the oil upgrading. In addition, silica nanoparticles grafted with a mass fraction of 12% polyethylene glycol were used as an additive to improve the stability of an alpha-olefin sulphonate-based foam. The nanofluid formulation for the in situ upgrading process was carried out through thermogravimetric analysis and measurements of zeta potential during eight days to find the best concentration of nanoparticles and surfactant, respectively. The displacement test was carried out in different stages, including, (i) basic characterization, (ii) steam injection in the absence of nanofluids, (iii) steam injection after soaking with nanofluid for in situ upgrading, (iv) N2 injection, and (v) steam injection after foaming nanofluid. Increase in the oil recovery of 8.8%, 3%, and 5.5% are obtained for the technology assisted by the nanocatalyst-based nanofluid, after the nitrogen injection, and subsequent to the thermal foam injection, respectively. Analytical methods showed that the oil viscosity was reduced 79%, 77%, and 31%, in each case. Regarding the asphaltene content, with the presence of the nanocatalyst, it decreased from 28.7% up to 12.9%. Also, the American Petroleum Institute (API) gravity values increased by up to 47%. It was observed that the crude oil produced after the foam injection was of higher quality than the crude oil without treatment, indicating that the thermal foam leads to a better swept of the porous medium containing upgraded oil.

Friction theory prediction of crude oil viscosity at reservoir conditions based on dead oil properties

2003 ◽  
Vol 212 (1-2) ◽  
pp. 233-243 ◽  
Author(s):  
Sergio E Quiñones-Cisneros ◽  
Claus K Zéberg-Mikkelsen ◽  
Erling H Stenby
Keyword(s):  
Crude Oil ◽  
Oil Viscosity ◽  
Friction Theory ◽  
Reservoir Conditions

scholarly journals CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

Energies ◽  
2021 ◽  
Vol 14 (1) ◽  
pp. 233
Author(s):  
Widuramina Amarasinghe ◽  
Ingebret Fjelde ◽  
Nils Giske ◽  
Ying Guo
Keyword(s):  
Porous Media ◽  
Crude Oil ◽  
Water Solution ◽  
Co2 Storage ◽  
Bromothymol Blue ◽  
Power Relationship ◽  
Dimensionless Time ◽  
3 Dimensional ◽  
Reservoir Conditions ◽  
Unconsolidated Porous Media

During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by diffusion followed by a density gradient that leads to a convective flow. Studies are available where CO2 convective mixing have been studied in water phase but limited in oil phase. This study was conducted to reach this gap, and experiments were conducted in a vertically packed 3-dimensional column with oil-saturated unconsolidated porous media at 100 bar and 50 °C (representative of reservoir pressure and temperature conditions). N-Decane and crude oil were used as oils, and glass beads as porous media. A bromothymol blue water solution-filled sapphire cell connected at the bottom of the column was used to monitor the CO2 breakthrough. With the increase of the Rayleigh number, the CO2 transport rate in n-decane was found to increase as a function of a second order polynomial. Ra number vs. dimensionless time τ had a power relationship in the form of Ra = c×τ−n. The overall pressure decay was faster in n-decane compared to crude oil for similar permeability (4 D), and the crude oil had a breakthrough time three times slower than in n-decane. The results were compared with similar experiments that have been carried out using water.

Heavy crude oil viscosity reduction and rheology for pipeline transportation

Fuel ◽  
2010 ◽  
Vol 89 (5) ◽  
pp. 1095-1100 ◽  
Author(s):  
Shadi W. Hasan ◽  
Mamdouh T. Ghannam ◽  
Nabil Esmail
Keyword(s):  
Crude Oil ◽  
Viscosity Reduction ◽  
Heavy Crude Oil ◽  
Pipeline Transportation ◽  
Oil Viscosity ◽  
Heavy Crude

Prediction of crude oil viscosity curve using artificial intelligence techniques

2012 ◽  
Vol 86-87 ◽  
pp. 111-117 ◽  
Author(s):  
M.A. Al-Marhoun ◽  
S. Nizamuddin ◽  
A.A. Abdul Raheem ◽  
S. Shujath Ali ◽  
A.A. Muhammadain
Keyword(s):  
Artificial Intelligence ◽  
Crude Oil ◽  
Oil Viscosity ◽  
Artificial Intelligence Techniques ◽  
Viscosity Curve
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