The Effect of the Relative Permeability Ratio, the Oil Gravity, and the Solution Gas-Oil Ratio on the Primary Recovery From a Depletion Type Reservoir

10.2118/469-g ◽  
1955 ◽  
Vol 204 (01) ◽  
pp. 120-127 ◽  
Author(s):  
J.J. Arps ◽  
T.G. Roberts
Keyword(s):  
Relative Permeability ◽  
Gas Oil ◽  
Permeability Ratio ◽  
Solution Gas

Effect of Temperature on the Gas/Oil Relative Permeability of Orinoco Belt Foamy Oil

SPE Journal ◽  
2016 ◽  
Vol 21 (01) ◽  
pp. 170-179 ◽  
Author(s):  
Songyan Li ◽  
Zhaomin Li
Keyword(s):  
Relative Permeability ◽  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Viscosity Reduction ◽  
Gas Oil ◽  
Foamy Oil ◽  
Solution Gas Drive ◽  
Gas Drive ◽  
Solution Gas

Summary Foamy-oil flow has been successfully demonstrated in laboratory experiments and site applications. On the basis of solution-gas-drive experiments with Orinoco belt heavy oil, the effects of temperature on foamy-oil recovery and gas/oil relative permeability were investigated. Oil-recovery efficiency increases and then decreases with temperature and attains a maximum value of 20.23% at 100°C. The Johnson-Bossler-Naumann (JBN) method has been proposed to interpret relative permeability characteristics from solution-gas-drive experiments with Orinoco belt heavy oil, neglecting the effect of capillary pressure. The gas relative permeability is lower than the oil relative permeability by two to four orders of magnitude. No intersection was identified on the oil and gas relative permeability curves. Because of an increase in temperature, the oil relative permeability changes slightly, and the gas relative permeability increases. Thermal recovery at an intermediate temperature is suitable for foamy oil, whereas a significantly higher temperature can reduce foamy behavior, which appears to counteract the positive effect of viscosity reduction. The main reason for the flow characteristics of foamy oil in porous media is the low gas mobility caused by the oil components and the high viscosity. High resin and asphaltene concentrations and the high viscosity of Orinoco belt heavy oil increase the stability of bubble films and prevent gas breakthrough in the oil phase, which forms a continuous gas, compared with the solution-gas drive of light oil. The increase in the gas relative permeability with temperature is caused by higher interfacial tensions and the bubble-coalescence rate at high temperatures. The experimental results can provide theoretical support for foamy-oil production.

The Calculated Performance of Solution-Gas-Drive Reservoirs

1961 ◽  
Vol 1 (03) ◽  
pp. 142-152 ◽  
Author(s):  
J.S. Levine ◽  
M. Prats
Keyword(s):  
Steady State ◽  
Differential Equations ◽  
Relative Permeability ◽  
Absolute Permeability ◽  
Gas Oil ◽  
Pvt Properties ◽  
Partial Differential ◽  
Solution Gas Drive ◽  
Gas Drive ◽  
Solution Gas

Abstract Several methods are available for calculating the performance of solution-gas-drive reservoirs from the PVT properties of the oil and from the relative permeability and other properties of the formation. These methods require a number of simplifying assumptions. The present method of computation has made use of a high-speed computer to solve simultaneously the nonlinear partial differential equations that describe two-phase flow by solution-gas drive in order to calculate the performance of a reservoir. Some of the results obtained by the nonlinear partial differential equation solution are compared with those obtained with an approximate method, which has been called the semi-steady-state solution. The pressure and saturation profiles from the wellbore to outer boundary calculated by the two methods are compared for one constant-terminal-rate case and two constant-terminal-pressure cases. The agreement in these profiles, as well as in the values of average reservoir pressure and cumulative recovery, leads to the conclusion that, for most engineering calculations, the semi-steady-state method will give a reasonable approximation to the numerical solution of the differential equations describing solution-gas drive. An unfavorable (as regards ultimate oil production) set of relative permeability curve was used in the calculations in the belief that the effect of the parameters which were studied would be emphasized to a greater degree. Furthermore, the reservoir was assumed to be completely homogeneous, and these results should not be considered applicable to any other type of reservoir. Gravity effects are not considered. The absolute permeability was varied from 25 to 0.5 md. At an economic limit of 2 B/D, the recovery for a 25-md reservoir is about 1.8 times as great as that for a 0.5-md reservoir. The effect of permeability on the producing gas-oil ratio is minor. Once PVT properties of the oil and the relative permeability properties of the reservoir are fixed, the producing gas-oil ratio is found to be a function of the fraction of oil recovered.

scholarly journals Modelling the Molecular Permeation through Mixed-Matrix Membranes Incorporating Tubular Fillers

Membranes ◽  
2021 ◽  
Vol 11 (1) ◽  
pp. 58
Author(s):  
Ali Zamani ◽  
F. Handan Tezel ◽  
Jules Thibault
Keyword(s):  
Aspect Ratio ◽  
Relative Permeability ◽  
Polymer Matrix ◽  
Volume Fraction ◽  
Mixed Matrix Membranes ◽  
Analytical Prediction ◽  
Mixed Matrix ◽  
Permeability Ratio ◽  
Filler Volume Fraction ◽  
Matrix Membranes

Membrane-based processes are considered a promising separation method for many chemical and environmental applications such as pervaporation and gas separation. Numerous polymeric membranes have been used for these processes due to their good transport properties, ease of fabrication, and relatively low fabrication cost per unit membrane area. However, these types of membranes are suffering from the trade-off between permeability and selectivity. Mixed-matrix membranes, comprising a filler phase embedded into a polymer matrix, have emerged in an attempt to partly overcome some of the limitations of conventional polymer and inorganic membranes. Among them, membranes incorporating tubular fillers are new nanomaterials having the potential to transcend Robeson’s upper bound. Aligning nanotubes in the host polymer matrix in the permeation direction could lead to a significant improvement in membrane permeability. However, although much effort has been devoted to experimentally evaluating nanotube mixed-matrix membranes, their modelling is mostly based on early theories for mass transport in composite membranes. In this study, the effective permeability of mixed-matrix membranes with tubular fillers was estimated from the steady-state concentration profile within the membrane, calculated by solving the Fick diffusion equation numerically. Using this approach, the effects of various structural parameters, including the tubular filler volume fraction, orientation, length-to-diameter aspect ratio, and permeability ratio were assessed. Enhanced relative permeability was obtained with vertically aligned nanotubes. The relative permeability increased with the filler-polymer permeability ratio, filler volume fraction, and the length-to-diameter aspect ratio. For water-butanol separation, mixed-matrix membranes using polydimethylsiloxane with nanotubes did not lead to performance enhancement in terms of permeability and selectivity. The results were then compared with analytical prediction models such as the Maxwell, Hamilton-Crosser and Kang-Jones-Nair (KJN) models. Overall, this work presents a useful tool for understanding and designing mixed-matrix membranes with tubular fillers.

Pressure-Volume-Temperature Correlations for Gulf of Mexico Crude Oils

1998 ◽  
Vol 1 (05) ◽  
pp. 416-420 ◽  
Author(s):  
G.E. Petrosky ◽  
F. Farshad
Keyword(s):  
Technical Conference ◽  
Pressure Solution ◽  
Gas Oil ◽  
Pvt Properties ◽  
Volume Factor ◽  
Original Manuscript ◽  
Oil Formation Volume Factor ◽  
Solution Gas ◽  
Oil Formation ◽  
Temperature Correlations

This paper (SPE 51395) was revised for publication from paper SPE 26644, first presented at the 1993 SPE Annual Technical Conference and Exhibition, Houston, 3-6 October. Original manuscript received for review 25 October 1993. Revised manuscript received 1 October 1997. Paper peer approved 28 January 1998. Summary New empirical pressure-volume-temperature (PVT) correlations for estimating bubblepoint pressure, solution gas-oil ratio (GOR), bubblepoint oil formation volume factor (FVF), and undersaturated isothermal oil compressibility have been developed as a function of commonly available field data. Results show that these PVT properties can be predicted with average absolute errors ranging from 0.64% for bubblepoint oil FVF to 6.66% for undersaturated isothermal oil compressibility. P. 416

Measurement of Gas-Oil Relative Permeability in Unconventional Rocks

2019 ◽  
Author(s):  
Shreerang S. Chhatre ◽  
Amy L. Chen ◽  
Muhammed Al-Rukabi ◽  
Daniel W. Berry ◽  
Robert Longoria ◽  
...  
Keyword(s):  
Relative Permeability ◽  
Gas Oil
Sign in / Sign up

Export Citation Format

Share Document