Carbon Dioxide Flooding — Fundamentals

Mungan, Necmettin

doi:10.1007/978-94-009-6140-1_5

Cited by 38 publications

(28 citation statements)

References 13 publications

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“…(e.g. Mungan (1981), Langston et al (1988), Tanner et al (1992), Kittridge (1992), Hsu et al (1995), Harpole et al (1996), Ring and Smith (1995), Brokmeyer et al (1996), Flanders and DePauw (1993), Bellavance (1996), Pittaway and Rosalto (1991)). …”

Section: Introductionmentioning

confidence: 96%

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Lindeloff¹,

Mogensen²,

Oil³

et al. 2013

Day 2 Tue, October 01, 2013

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The phase behavior of two Middle East reservoir fluids mixed with CO 2 has been studied. The experimental work includes quantification of VLLE/LLE behavior studied in a visual high pressure PVT cell.To investigate the effect of dispersion on slim tube recoveries, experiments were performed using two different tube sizes. One of the reservoir fluids was found to be miscible with CO 2 at the reservoir temperature while a liquid-liquid split persisting at high pressure was observed for the other fluid. As the two liquid phases had approximately the same mobility, a high slimtube recovery was seen for the latter fluid despite the liquid-liquid split. EOS models have been developed matching the swelling and slimtube data and confirming the observed VLLE and LLE phase behavior.The work has led to an improved understanding of how swelling and MMP data for CO 2 -crude oil systems is to be interpreted. An important observation is that a miscible drive is not always attainable for a reservoir fluid undergoing CO 2 gas injection.

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Section: Introductionmentioning

confidence: 96%

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Lindeloff¹,

Mogensen²,

Oil³

et al. 2013

Day 2 Tue, October 01, 2013

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show abstract

“…[10][11][12][13][14][15][16][17][18][19][20][21][22] All these correlations have limitations that can result in large discrepancies when compared with experimentally determined MMP values. Some of them disregarded the C 1 through C 4 fraction and were based only on reservoir temperature and the molar weight of C 5+ in the reservoir oil.…”

Section: Introductionmentioning

confidence: 99%

Effect of Solution Gas in Oil on CO<sub>2</sub> Minimum Miscibility Pressure

Dong

Huang

Srivastava

1999

Annual Technical Meeting

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In a miscible CO 2 flood, multicontact miscibility between the injected CO 2 and the reservoir fluid can be achieved at pressures greater than a minimum value. This minimum miscibility pressure (MMP) is a key parameter for assessing the applicability and design of a miscible gas flood for an oil reservoir. The effect on CO 2 MMP of reservoir temperature, oil composition (molecular weight of C 5+ or C 7+ fraction), and the purity of injected CO 2 have been investigated extensively. Numerous empirically derived CO 2 MMP correlations have been reported in the literature. However, how the solution gas in oil influences the CO 2 MMP is not well understood.In this study, the rising bubble apparatus (RBA) was used to determine the CO 2 MMP for various oils. RBA tests permit direct observation of changes in bubble behaviour and thus offered insight into the phase behaviour for the CO 2 -reservoir fluid system. The CO 2 MMPs were estimated for two Steelman reservoir fluids with a high gas-oil ratio, the partially flashed reservoir fluids, and the dead oils. The composition of solution gas of each partially flashed reservoir fluid was determined and the effects of different gas components were analysed. The MMP was also determined and discussed for Weyburn reservoir fluids which had a low gas-oil ratio with pure and impure CO 2 . The results of this study demonstrated that the effect of solution gas in oil on CO 2 MMP could be significant. Furthermore, achieving a miscible CO 2 flood (in a reservoir with a Steelman-like reservoir fluid) could be possible at a lower operating pressure than the measured CO 2 MMP, by partially depleting the reservoir. This may be the only option for some reservoirs which cannot sustain the relatively high pressure required for achieving miscibility.

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“…When oil composition data is missing, it is practical to use a correlation between oil API gravity and C5C oil molecular weight (Mungan, 2003). Another parameter, known as irreducible water saturation, is determined from the correlations, which assume that petro-physical interrelationships are controlled by pore geometry.…”

Section: Analysis With Co 2 -Prophet Toolmentioning

confidence: 99%

The Evaluation of an Immiscible-CO₂Enhanced Oil Recovery Technique for Heavy Crude Oil Reservoirs

Kök

Örs

2012

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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Carbon Dioxide Flooding — Fundamentals

Cited by 38 publications

References 13 publications

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Effect of Solution Gas in Oil on CO<sub>2</sub> Minimum Miscibility Pressure

The Evaluation of an Immiscible-CO₂Enhanced Oil Recovery Technique for Heavy Crude Oil Reservoirs

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Carbon Dioxide Flooding — Fundamentals

Cited by 38 publications

References 13 publications

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Effect of Solution Gas in Oil on CO<sub>2</sub> Minimum Miscibility Pressure

The Evaluation of an Immiscible-CO2Enhanced Oil Recovery Technique for Heavy Crude Oil Reservoirs

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The Evaluation of an Immiscible-CO₂Enhanced Oil Recovery Technique for Heavy Crude Oil Reservoirs