Determination of Water-Oil Interfacial Area during 3-Phase Gravity Drainage in Porous Media

Schaefer, Charles E.; DiCarlo, David A.; Blunt, Martin J.

doi:10.1006/jcis.1999.6604

Cited by 50 publications

(62 citation statements)

References 23 publications

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“…To our knowledge there are no experimental systems which gives data on average velocity of interfaces, although Magnetic Resonance Imaging (MRI) may potentially be used to give such data, see for example Johns and Gladden [31] for results in this direction. However, over the last decade several groups have provided data on interfacial areas, in particular related to research on NAPL, see for example [5,10,11,6] We have chosen to use experimental results obtained by Schaefer et.al. [6], as a validation experiment for our network code.…”

Section: Validation Of Network Modelmentioning

confidence: 99%

“…However, over the last decade several groups have provided data on interfacial areas, in particular related to research on NAPL, see for example [5,10,11,6] We have chosen to use experimental results obtained by Schaefer et.al. [6], as a validation experiment for our network code. In one of their experiments, a uniformly packed sand of cross-sectional area 5.1 cm 2 was initially completely water saturated.…”

Section: Validation Of Network Modelmentioning

confidence: 99%

“…We next explain the averaging procedures used in our modeling, with a focus on averaged variables associated with interfacial areas, especially average interfacial velocity. We compare our results to laboratory measurements for interfacial area in a two-fluid system, [6], then provide computational results for interfacial area dynamics for both stable and unstable displacements. Finally, we compare our results to a simple theoretical conjecture relating interfacial velocity to fluid phase velocities, and conclude the paper with a discussion of the role of computational models and their relationship to new theoretical developments in the field of multiphase flow dynamics.…”

Section: Introductionmentioning

confidence: 98%

“…While interfaces control many important properties of multi-phase systems, quantitative characterization of these interfaces has received relatively little attention in the porous media literature. Recent theoretical work of Gray and Hassanizadeh [1][2][3], and computational work of Miller and coworkers [4], Blunt and coworkers [5,6], Reeves, Held, and Celia [7][8][9], and Saripalli and coworkers [10,11], among others, have provided initial efforts to quantify bulk interfacial area, and to explore possible functional relationships between interfacial area, saturation, and capillary pressure. However, there has been very little work to quantify dynamical aspects of interfacial area.…”

Section: Introductionmentioning

confidence: 99%

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A pore network model for calculation of interfacial velocities

Nordhaug

Celia

Dahle

2003

Advances in Water Resources

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Two-phase flow in porous media is characterized by fluid-fluid interfaces that separate fluid phases at the pore scale. These interfaces support pressure differences between phases, and their dynamics lead to changes in phase saturation within the porous medium. Dynamic pore-scale network models mathematically track the dynamic position of each fluid-fluid interface through a pore network, based on imposed boundary conditions, fluid and solid properties, and geometric characteristics of the network. Because these models produce a detailed description of both phase and interface dynamics, results from these models can be volume-averaged to provide values for many macroscopic variables. These include traditional variables such as saturation and macroscopic capillary pressure, as well as non traditional variables such as amount of interfacial area in the averaging volume. With appropriate geometric definitions in the dynamic pore-scale model, a new algorithm may be included in the pore-scale network model to calculate a new variable: average interfacial velocity. This algorithm uses local information in any pore that contains a fluid-fluid interface to estimate the velocity of that interface over a time step. Summation over all interfaces in the network provides a measure of average velocity. Computations for dynamic drainage experiments indicate that this average interfacial velocity is well-defined and exhibits distinct behavior for stable and unstable displacements. Comparison of calculated interfacial velocities to a theoretical conjecture on the functional dependence of this macroscopic variable demonstrates another important use of pore-scale model, namely testing of new theories involving non traditional variables.

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Section: Validation Of Network Modelmentioning

confidence: 99%

Section: Validation Of Network Modelmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 98%

Section: Introductionmentioning

confidence: 99%

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A pore network model for calculation of interfacial velocities

Nordhaug

Celia

Dahle

2003

Advances in Water Resources

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“…Bradford and Lei (1997) makes theoretical predictions for the changes in interfacial areas during imbibition and drainage whereas Jain et al (2003) and Gladkikh et al (2003) rely on the tracer technique to estimate the same quantities In our research, actual core samples from outcrops are used for analysis. This involves a greater of degree of complication as compared to the work done by other researchers (Morrow, 1970, Kim et al, 1997, Gladkikh et al, 2003, Bradford and Lei, 1997, Scheafer et al, 2000aand 2000b who worked with unconsolidated media (either bead pack or soil). Preliminary analysis will be done for Berea sandstone and a limestone sample.…”

Section: Introductionmentioning

confidence: 99%

Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action, and Oil Recovery From Fractured Reservoirs by Spontaneous Imbibition

Morrow¹,

Fischer²,

Liu³

et al. 2004

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The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition.A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the nonwetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models.In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

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Comparison of fluid‐fluid interfacial areas measured with X‐ray microtomography and interfacial partitioning tracer tests for the same samples

McDonald

Carroll

Brusseau

2016

Water Resources Research

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Two different methods are currently used for measuring interfacial areas between immiscible fluids within 3‐D porous media, high‐resolution microtomographic imaging and interfacial partitioning tracer tests (IPTT). Both methods were used in this study to measure nonwetting/wetting interfacial areas for a natural sand. The microtomographic imaging was conducted on the same packed columns that were used for the IPTTs. This is in contrast to prior studies comparing the two methods, for which in all cases different samples were used for the two methods. In addition, the columns were imaged before and after the IPTTs to evaluate the potential impacts of the tracer solution on fluid configuration and attendant interfacial area. The interfacial areas measured using IPTT are ∼5 times larger than the microtomographic‐measured values, which is consistent with previous work. Analysis of the image data revealed no significant impact of the tracer solution on NAPL configuration or interfacial area. Other potential sources of error were evaluated, and all were demonstrated to be insignificant. The disparity in measured interfacial areas between the two methods is attributed to the limitation of the microtomography method to characterize interfacial area associated with microscopic surface roughness due to resolution constraints.

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Determination of Water-Oil Interfacial Area during 3-Phase Gravity Drainage in Porous Media

Cited by 50 publications

References 23 publications

A pore network model for calculation of interfacial velocities

A pore network model for calculation of interfacial velocities

Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action, and Oil Recovery From Fractured Reservoirs by Spontaneous Imbibition

Comparison of fluid‐fluid interfacial areas measured with X‐ray microtomography and interfacial partitioning tracer tests for the same samples

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