Solubility Of Methane, Nitrogen, and Carbon Dioxide in Bitumen and Water for SAGD Modelling

Al-Murayri, Mohammed Taha; Harding, Thomas G.; Maini, Brij B.

doi:10.2118/148630-pa

Cited by 26 publications

(9 citation statements)

References 1 publication

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“…Under the same conditions, the solubility of nitrogen in water is less than that of methane, which results in the liquid drainage rate of the nitrogen foam being less than that of the methane foam, so the nitrogen foam has better stability. 29 Finally, surfactant S-B was selected. The amphoteric surfactant was compatible with the other types of surfactants, especially those capable of accepting a proton, and it may also exhibit synergy with the anionic surfactant through electrostatic interactions.…”

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

“…Regardless of whether NPs are added or not, the pressure increase rate and the amplitude of the methane foam are weaker than those of the nitrogen foam, which is related to the properties of methane and nitrogen. 29 We placed the foam generated before blocking on a glass slide, covered with a cover glass, and observed the change in its shape with time under a microscope. We used three time nodes (initial time, 5 min, and 10 min) to compare the particle size changes and particle size normal distribution curves of the four foams, as shown in Figure 13.…”

Section: Resultsmentioning

confidence: 99%

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Investigation of the Effect of Nanoparticle-Stabilized Foam on EOR: Nitrogen Foam and Methane Foam

Zhao

et al. 2020

ACS Omega

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In recent years, studies conducted on foam stabilization have focused on nanoparticles by generating strong adsorption at the interface to stabilize the foam under harsh reservoir conditions. Meanwhile, the selection of a gas source is also of great importance for foam performance. In this study, a mixed system of surfactants was selected, and the foamability and foam stability of nitrogen and methane were evaluated according to the improved jet method. After adding modified SiO 2 nanoparticles, the foam-related parameters were analyzed. The plugging abilities of the different foams were compared through core-flooding experiments, and the oil displacement effects of the different foams were compared through microfluidic experiments. The results show that the amphoteric surfactant betaine has an excellent synergistic effect on the anionic surfactant SDS. The methane foam produced using the jet method has a larger initial volume than the nitrogen foam, but its stability is poor. The half-life of the nitrogen foam is about two times that of the methane foam. After adding 1.0 wt % SiO 2 nanoparticles to the surfactant solution, the viscosity and stability of the formed foam improve. However, the maximum viscosity of the surfactant nanoparticle foam (surfactant-NP foam) is 53 mPa·s higher than that of the surfactant foam. In the core-flooding experiment, the plugging performance of the methane foam was worse than that of the nitrogen foam, and in the microfluidic experiment, the oil displacement abilities of the methane foam and the nitrogen foam were similar. The plugging performance and the oil displacement effect of the foam are greatly improved by adding nanoparticles. The surfactant-NP foam flooding has a better oil displacement effect and can enhance the recovery factor by more than 30%. Under actual high-pressure reservoir conditions, although the stability of the methane foam is weaker than that of the nitrogen foam, some methane may be dissolved in the crude oil to decrease the viscosity after the foam collapses, which leads to the methane foam being the preferred method in oilfields.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

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Investigation of the Effect of Nanoparticle-Stabilized Foam on EOR: Nitrogen Foam and Methane Foam

Zhao

et al. 2020

ACS Omega

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“…There have been numerous numerical and experimental studies investigating various aspects of solvent-aided recovery processes. − Al-Murayri et al considered the impact of the noncondensable gases as possible solvents in a hybrid process with the conventional SAGD. Their simulation results revealed that while co-injection of a noncondensable gas such as methane reduces the heat loss to the overburden, it negatively impacts the oil recovery by affecting the steam condensation.…”

Section: Introductionmentioning

confidence: 99%

Propane-Aided Leaching of Bitumen from Oilsands

Santa

Sabet

2020

Energy Fuels

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We report highly fine-grid numerical simulations of solvent-aided bitumen leaching using propane as a solvent. These simulations allowed us to observe the detailed physics of the drainage process, which is otherwise impossible in coarse-grid simulations. Our results revealed significant fingering of the solvent into bitumen as a result of viscosity and density contrasts, which is in line with the previous experimental observation of bitumen leaching by toluene. Based on our simulation results, the drainage process undergoes two distinct infinite-acting and finite-acting periods, with more than two-thirds of the drainage taking place during the former. Interestingly, the rate of drainage of bitumen is constant during the infinite-acting period, and it is independent of formation thickness. Using the results of our simulations, we found out that the rate of drainage of bitumen is scaled linearly with formation permeability. The results of this work shed light on the fine-scale physics of the bitumen leaching process by solvents and pave the way for the development of new recovery processes.

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“…Core flooding experiments have also been conducted to study the ability of immiscible CO 2 to increase oil recovery [18]. Immiscible CO 2 injection has also been coupled with other injection fluids such as water, and steam in hopes of increasing oil recovery [19][20][21]. Due to the abundance of methods by which oil swelling can be measured, and the many ways by which immiscible CO 2 injection can be applied, it is important to provide a guideline to these methods and their advantages and limitations.…”

Section: Introductionmentioning

confidence: 99%

A data analysis of immiscible carbon dioxide injection applications for enhanced oil recovery based on an updated database

Fakher

Imqam

2020

SN Appl. Sci.

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Carbon dioxide (CO 2) injection is an enhanced oil recovery technique used worldwide to increase oil recovery from hydrocarbon reservoirs. Immiscible CO 2 injection involves injecting the CO 2 into the reservoir at a pressure below which it will become miscible in the oil. Even though immiscible CO 2 injection has been applied extensively, very little research has been conducted to provide a comprehensive understanding of the mechanism and the applications of immiscible CO 2 injection. This research performs an in-depth data analysis is performed based on more than 200 experiments and 20 field tests from more than 40 researches to show the conditions at which immiscible CO 2 injection has been applied and the most frequent application conditions. Histograms and boxplots have been generated for temperature, CO 2 injection pressure, oil viscosity, molecular weight, and API gravity, CO 2 solubility, and finally oil swelling to show the ranges and frequency of application for all these parameters. Finally, crossplots have been generated from the data to show the relation of pressure and temperature to CO 2 solubility and oil swelling. The crossplots function to illustrate a relation between the variables and draws a conclusion as to what effect each parameter will have on the other.

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Solubility Of Methane, Nitrogen, and Carbon Dioxide in Bitumen and Water for SAGD Modelling

Cited by 26 publications

References 1 publication

Investigation of the Effect of Nanoparticle-Stabilized Foam on EOR: Nitrogen Foam and Methane Foam

Investigation of the Effect of Nanoparticle-Stabilized Foam on EOR: Nitrogen Foam and Methane Foam

Propane-Aided Leaching of Bitumen from Oilsands

A data analysis of immiscible carbon dioxide injection applications for enhanced oil recovery based on an updated database

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