scholarly journals Effect of Temperature on Athabasca Type Heavy Oil – Water Relative Permeability Curves in Glass Bead Packs

2012 ◽  
Vol 2 (2) ◽  
Author(s):  
Mohammad Ashrafi ◽  
Yaser Souraki ◽  
Ole Torsaeter
Keyword(s):  
Relative Permeability ◽  
Heavy Oil ◽  
Glass Bead ◽  
Effect Of Temperature ◽  
Oil Water ◽  
Relative Permeability Curves

Interrelationship of Temperature and Wettability on the Relative Permeability of Heavy Oil in Diatomaceous Rocks (includes associated discussion and reply)

2006 ◽  
Vol 9 (03) ◽  
pp. 239-250 ◽  
Author(s):  
Josephina M. Schembre ◽  
Guo-Qing Tang ◽  
Anthony R. Kovscek
Keyword(s):  
Elevated Temperature ◽  
Capillary Pressure ◽  
Relative Permeability ◽  
Heavy Oil ◽  
Thermal Recovery ◽  
Wettability Alteration ◽  
Effect Of Temperature ◽  
Phase Saturation ◽  
Effects Of Temperature ◽  
Relative Permeability Curves

Summary The evaluation of thermal-recovery processes requires relative permeability functions, as well as information about the effects of temperature on these functions. There are significant challenges encountered when estimating relative permeability from laboratory data, such as the accuracy of measurements and generalized assumptions in the interpretation techniques. A novel method is used here to estimate relative permeability and capillary pressure from in-situ aqueous-phase saturation profiles obtained from X-ray computerized tomography (CT) scanning during high-temperature imbibition experiments. Relative permeability and capillary pressure functions are interpreted simultaneously, including possible nonequilibrium effects. Results obtained show a systematic shift toward increased water-wettability with increasing temperature for diatomite reservoir core. The measured changes in relative permeability are linked to the effect of temperature on the adhesion of oil-coated fines to rock surfaces and, ultimately, to rock/fluid interactions. Introduction An understanding of the effects of temperature on wettability and relative permeability functions is essential to optimize and forecast the results of diatomite thermal-recovery projects. Most of the controversy regarding the effect of temperature on relative permeability is caused by the mechanisms involved in rock-wettability change that are dependent on both fluid and rock characteristics. A secondary, and equally important, problem is the technique used to process the data, such as oil recovery, phase saturation, or pressure, as well as data interpretation in the form of relative permeability curves. This paper re-examines the influence of temperature on rock/fluid interactions and heavy-oil relative permeability of diatomite from a core-level experimental and a pore-level perspective. We find experimentally and theoretically that fine particles are released from pore walls under conditions of elevated temperature, high pH, and moderate to low aqueous-phase salinity. The release of fines correlates with changes in relative permeability curves toward greater water-wetness. The mechanism of fines release provides new understanding of a mode of wettability alteration at elevated temperature. This paper is organized as follows. First, a synopsis of the literature is presented, followed by a discussion of recent developments in the understanding of wettability alteration. Second, the experimental method and the relative permeability interpretative methodology are outlined. Third, relative permeability results interpreted from field core samples at temperature are presented. Discussion and conclusions round out the paper.

Analytical Solutions and Derivation of Relative Permeabilities for Water-Heavy Oil Displacement and Gas-Heavy Oil Gravity Drainage Under Non-Isothermal Conditions

2016 ◽  
Vol 19 (01) ◽  
pp. 181-191 ◽  
Author(s):  
F. J. Argüelles-Vivas ◽  
T.. Babadagli
Keyword(s):  
Temperature Gradient ◽  
Relative Permeability ◽  
Heavy Oil ◽  
Variable Temperature ◽  
Spontaneous Imbibition ◽  
Analytical Models ◽  
Gravity Drainage ◽  
Positive Temperature ◽  
Relative Permeability Curves ◽  
Isothermal Gas

Summary Analytical models were developed for non-isothermal gas/heavy-oil gravity drainage and water-heavy oil displacements in round capillary tubes including the effects of a temperature gradient throughout the system. By use of the model solution for a bundle of capillaries, relative permeability curves were generated at different temperature conditions. The results showed that water/gas-heavy oil interface location, oil-drainage velocity, and production rate depend on the change of oil properties with temperature. The displacement of heavy oil by water or gas was accelerated under a positive temperature gradient, including the spontaneous imbibition of water. Relative permeability curves were greatly affected by temperature gradient and showed significant changes compared with the curves at constant temperature. Clarifications were made as to the effect of variable temperature compared with the constant (but high) temperatures throughout the bundle of capillaries.

Effect of Temperature on Heavy Oil/Water Relative Permeabilities

1999 ◽  
Author(s):  
Akin Serhat ◽  
Louis M. Castanier ◽  
William E. Brigham
Keyword(s):  
Heavy Oil ◽  
Effect Of Temperature ◽  
Relative Permeabilities ◽  
Oil Water
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