Foams for Controlling Water Production

Bhide, V.; Hirasaki, G.; Miller, C.; Puerto, M.; Robb, I.; Norman, L.

doi:10.2523/93273-ms

Cited by 3 publications

(15 citation statements)

References 15 publications

(21 reference statements)

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“…It should be noted that the theories introduced thus far (i.e., E, S, and B coefficients) have primarily been developed through observations of foam films and oil under very controlled circumstances and therefore may not correlate equally well to all foam tests applied with oil present. Experimental studies indicate varying degree of correlation between foam properties in bulk and porous media in the presence of oil and the calculated coefficients (Andrianov et al, 2011;Arnaudov et al, 2001;Basheva et al, 2000;Bergeron, 1993;Bhide et al, 2005;Dalland et al, 1992;Mannhardt et al, 2000;Raterman, 1989;Rohani et al, 2014;Vikingstad et al, 2006). Several of the abovementioned laboratory studies have also demonstrated that foam performance in the presence of oil can be strongly influenced by the particular test method, procedures and conditions applied.…”

Section: Bridging Coefficientmentioning

confidence: 99%

“…Foams can also reduce water flow. Several authors indicate that foams can survive in laboratory corefloods, at least in a weakened form, against several pore volumes of liquid injected (Aarra et al, 2011;Bernard et al, 1965Bernard et al, , 1980Bhide et al, 2005;Du et al, 2007;Nguyen et al 2009;Parlar et al, 1995;Seright, 1996;Zeilinger et al, 1995). Reduced foam stability to subsequent liquid injections has been discussed in terms of surfactant dilution, gas expansion and gas dissolution into the injected liquid phase.…”

Section: Water Blocking Abilitiesmentioning

confidence: 99%

“…Several authors have also suggested that gas dissolution could have significant effects on the foam stability in porous media against subsequent water injection after foam generation (Bhide et al, 2005;Nguyen et al, 2009;Zeilinger et al, 1995). Comparative studies indicate that the CO 2 -foams are less effective to reduce water flow compared with foams having gas components with low solubility in water (e.g., air/N 2 and CH 4 ) (Aarra et al, 2011(Aarra et al, , 2014Seright, 1996).…”

Section: Gas/water Solubilitymentioning

confidence: 99%

“…Most experimental data in the literature suggest that oil reduces foam efficiency (i.e., decreases foam strength, stability and mobility control). However, many studies have shown that it is possible generate relatively strong and stable foams even in the presence of high oil fractions (Aarra et al, 1994(Aarra et al, , 1997(Aarra et al, , 2002Andrianov et al, 2011;Borchardt et al, 1987;Bhide et al, 2005;Casteel and Djabbarah, 1988;Chabert et al, 2013;Dalland et al, 1992;Friedmann and Jensen, 1986;Hanssen and Dalland, 1990;Holt et al, 1996;Maini and Ma, 1984;Mannhardt et al, 2000;Mannhardt and Svorstøl, 1999;McPhee et al, 1988;Parlar et al, 1995;Simjoo et al, 2013b;Solbakken, 2013;Strycker et al, 1987;Svorstøl et al, 1997;Tortopidis and Shallcross, 1994;Vikingstad and Aarra, 2009).…”

Section: Introductionmentioning

confidence: 99%

“…For some foam formulations, emulsion formation appear to have reduced gas mobility in porous media and increase foam stability in bulk foam experiments, beyond that achieved in the absence of oil. Emulsification of oil may be desirable or undesirable but should not be ignored (Aarra et al, 2011;Bian et al, 2012;Bernard et al, 1980;Bhide et al, 2005;Chabert et al, 2012Chabert et al, , 2014Kuhlman, 1990;Mannhardt et al, 2000;Mukherjee et al,. 2014;Vikingstad, 2006;Wassmuth et al, 2000;Yang and Reed, 1989;Yin et al, 2009).…”

Section: Introductionmentioning

confidence: 99%

See 4 more Smart Citations

Properties of N2- and CO2-foams as a function of pressure

Aarra

Skauge

Solbakken

et al. 2014

Journal of Petroleum Science and Engineering

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The last ~4.5 years have been the most exciting and challenging period in my life so far. I want to use this opportunity to thank at least some of the people who have supported me in one way or another during this period. I wish to express my gratitude to my supervisor Dr. Morten G. Aarra; thank you for sharing your knowledge with me, for your personal encouragement, and for the many good discussions. My co-supervisor, Professor Arne Skauge, deserves a special thank as well; thank you for scientific advice and assistance throughout the work, for giving me the opportunity to participate as a Master and PhD student at Uni CIPR, and for offering me a permanent position thereafter. Acknowledge goes to Hege Ommedal for her support as PhD-coordinator at the department of Chemistry. I am also thankful to other past and present colleagues at Uni CIPR who have made this time

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Section: Bridging Coefficientmentioning

confidence: 99%

Section: Water Blocking Abilitiesmentioning

confidence: 99%

Section: Gas/water Solubilitymentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

Properties of N2- and CO2-foams as a function of pressure

Aarra

Skauge

Solbakken

et al. 2014

Journal of Petroleum Science and Engineering

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Probing the Effect of Oil Type and Saturation on Foam Flow in Porous Media: Core-Flooding and Nuclear Magnetic Resonance (NMR) Imaging

et al. 2018

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The success of foam displacement in porous media largely depends on its stability, which is adversely impacted by the presence of oil. In this study, we present the results of an experimental investigation into the effect of oil type and saturation on foam rheology in Berea sandstone using the nuclear magnetic resonance imaging technique. The results of foam quality scan in the presence of remaining hexadecane was compared with those from the oil-free case. We showed that the calculated apparent viscosity values in the presence of remaining hexadecane were higher than those in the absence of oil except at very high foam qualities. This was attributed to the dominance of relative permeability reduction and generation of oil-in-water emulsions over the foam-weakening effect of oil. A closer analysis of the fluid distribution further allowed us to quantify the relative significance of the identified oil displacement mechanisms, namely, the increased capillary number, and the micellar solubilization. Additionally, we correlated the foam strength with the oil saturation from the foam-oil co-injection tests. Because of the detrimental effect of oil on foam stability, it is found that the apparent viscosity first decreases with increasing oil (hexadecane and octane) saturation; then, due to oil emulsification, apparent viscosity increases with oil saturation (or more strictly with the oil fractional flow). Compared to octane, hexadecane resulted in less foam destabilization and higher oil emulsification. The co-injection experiment with crude oil exhibited a similar behavior to octane. Findings from this study suggest that, despite the destabilizing impact of oil on foam, the resulting steady-state apparent viscosities could be much larger than the viscosity of the in situ oil. This leads to a favorable mobility ratio during the oil-displacement process.

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Effect of Water Solubility on Carbon Dioxide Foam Flow in Porous Media: An X-ray Computed Tomography Study

Beni

Farajzadeh

et al. 2008

Ind. Eng. Chem. Res.

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Carbon dioxide (CO 2 ) has found wide application in the water-alternating-foam (WAF) processes for enhanced oil recovery (EOR), but few research works have been reported concerning the effect of water solubility on the CO 2 foam rheology in a porous medium. In this paper, an X-ray computed tomography (CT) study is carried out to investigate CO 2 foam flow in a consolidated Bentheimer sandstone core saturated with surfactant solution under different system pressures. As a contrast gas with much lower solubility, nitrogen foam flow is also investigated to show the essence of gas solubility effects. Careful considerations were made on the selection of contrast gases, surfactant, and experimental procedures to focus on the effect of water solubility of the gas on foam rheology in porous media. It is observed from the experiments that CO 2 foam has lower pressure loss and clearly suppressed entrance effect. With the increment of system pressure, the liquid saturation increases and the pressure loss decreases significantly for CO 2 foam flow in the sample core, while little change can be observed for N 2 foam flow. It can be concluded that water solubility is one of the important influential factors for CO 2 foam rheology in porous media.

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Foams for Controlling Water Production

Cited by 3 publications

References 15 publications

Properties of N2- and CO2-foams as a function of pressure

Properties of N2- and CO2-foams as a function of pressure

Probing the Effect of Oil Type and Saturation on Foam Flow in Porous Media: Core-Flooding and Nuclear Magnetic Resonance (NMR) Imaging

Effect of Water Solubility on Carbon Dioxide Foam Flow in Porous Media: An X-ray Computed Tomography Study

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