scholarly journals Cardanol /SiO2 Nanocomposites for Inhibition of Formation Damage by Asphaltene Precipitation/Deposition in Light Crude Oil Reservoirs. Part II: Nanocomposite Evaluation and Coreflooding Test

ACS Omega ◽  
2020 ◽  
Vol 5 (43) ◽  
pp. 27800-27810
Author(s):  
Daniel López ◽  
Juan E. Jaramillo ◽  
Elizabete F. Lucas ◽  
Masoud Riazi ◽  
Sergio H. Lopera ◽  
...  
Keyword(s):  
Crude Oil ◽  
Oil Reservoirs ◽  
Formation Damage ◽  
Asphaltene Precipitation ◽  
Light Crude Oil ◽  
Sio2 Nanocomposites

Surfactant Enhanced Waterflood SEW in Medium and Light Crude Oil Reservoirs

2018 ◽  
Author(s):  
Lirio Quintero ◽  
Michael Deighton ◽  
Henry Nguyen ◽  
Eric Willmott ◽  
Oleksandr V. Kuznetsov ◽  
...  
Keyword(s):  
Crude Oil ◽  
Oil Reservoirs ◽  
Light Crude Oil

A Novel Air Flooding Technology for Light Crude Oil Reservoirs Applied under Reservoir Conditions

2018 ◽  
Vol 32 (4) ◽  
pp. 4942-4950 ◽  
Author(s):  
Tengfei Wang ◽  
Jiexiang Wang ◽  
Weipeng Yang ◽  
Shem Kalitaani ◽  
Zhiyu Deng
Keyword(s):  
Crude Oil ◽  
Oil Reservoirs ◽  
Light Crude Oil ◽  
Reservoir Conditions

Modeling Formation Damage by Asphaltene Deposition During Primary Oil Recovery

2005 ◽  
Vol 127 (4) ◽  
pp. 310-317 ◽  
Author(s):  
Shaojun Wang ◽  
Faruk Civan
Keyword(s):  
Experimental Data ◽  
Mathematical Model ◽  
Oil Recovery ◽  
Oil Reservoirs ◽  
Formation Damage ◽  
Asphaltene Precipitation ◽  
Vertical Wells ◽  
Core Flow ◽  
Asphaltene Deposition

Asphaltene precipitation and deposition during primary oil recovery and resulting reservoir formation damage are described by a phenomenological mathematical model. This model is applied using experimental data from laboratory core flow tests. The effect of asphaltene deposition on porosity, permeability, and the productivity of vertical wells in asphaltenic-oil reservoirs are investigated by simulation.

Construction, Validation, and Application of Digital Oil: Investigation of Asphaltene Association Toward Asphaltene-Precipitation Prediction

SPE Journal ◽  
2018 ◽  
Vol 23 (03) ◽  
pp. 952-968 ◽  
Author(s):  
S.. Sugiyama ◽  
Y.. Liang ◽  
S.. Murata ◽  
T.. Matsuoka ◽  
M.. Morimoto ◽  
...  
Keyword(s):  
Experimental Data ◽  
Liquid Phase ◽  
Crude Oil ◽  
Md Simulation ◽  
Heavy Fraction ◽  
Liquid Density ◽  
Asphaltene Precipitation ◽  
Viscosity Change ◽  
Light Crude Oil ◽  
Wide Range

Summary Digital oil, a realistic molecular model of crude oil for a target reservoir, opens a new door to understand properties of crude oil under a wide range of thermodynamic conditions. In this study, we constructed a digital oil to model a light crude oil using analytical experiments after separating the light crude oil into gas, light and heavy fractions, and asphaltenes. The gas and light fractions were analyzed by gas chromatography (GC), and 105 kinds of molecules, including normal alkanes, isoalkanes, naphthenes, alkylbenzenes, and polyaromatics (with a maximum of three aromatic rings), were directly identified. The heavy fraction and asphaltenes were analyzed by elemental analysis, molecular-weight (MW) measurement with gel-permeation chromatography (GPC), and hydrogen and carbon nuclear-magnetic-resonance (NMR) spectroscopy, and represented by the quantitative molecular-representation method, which provides a mixture model imitating distributions of the crude-oil sample. Because of the low weight concentration of asphaltenes in the light crude oil (approximately 0.1 wt%), the digital oil model was constructed by mixing the gas, light-, and heavy-fraction models. To confirm the validity of the digital oil, density and viscosity were calculated over a wide range of pressures at the reservoir temperature by molecular-dynamics (MD) simulations. Because only experimental data for the liquid phase were available, we predicted the liquid components of the digital oil at pressures lower than 16.3 MPa (i.e., the bubblepoint pressure) by flash calculation, and calculated the liquid density by MD simulation. The calculated densities coincided with the experimental values at all pressures in the range from 0.1 to 29.5 MPa. We calculated the viscosity of the liquid phase at the same pressures by two independent methods. The calculated viscosities were in good agreement with each other. Moreover, the viscosity change with pressure was consistent with the experimental data. As a step for application of digital oil to predict asphaltene-precipitation risk, we calculated dimerization free energy of asphaltenes (which we regarded as asphaltene self-association energy) in the digital oil at the reservoir condition, using MD simulation with the umbrella sampling method. The calculated value is consistent with reported values used in phase-equilibrium calculation. Digital oil is a powerful tool to help us understand mechanisms of molecular-scale phenomena in oil reservoirs and solve problems in the upstream and downstream petroleum industry.

Effect of pressure and CO2 content on the asphaltene precipitation in the light crude oil

2019 ◽  
Vol 38 (2) ◽  
pp. 116-123
Author(s):  
Jianguang Wei ◽  
Jiangtao Li ◽  
Xiaofeng Zhou ◽  
Xin Zhang
Keyword(s):  
Crude Oil ◽  
Asphaltene Precipitation ◽  
Effect Of Pressure ◽  
Light Crude Oil
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