Effect of Oxygen on Minimum Miscibility Pressure in Carbon Dioxide Flooding

Yang, Fulin; Zhao, Gui-Bing; Adidharma, Hertanto; Towler, Brian F.; Radosz, Maciej

doi:10.1021/ie061279g

Cited by 23 publications

(22 citation statements)

References 24 publications

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“…To ensure miscible conditions, the experiment pressure, controlled by the back pressure regulator (BPR), is at 20% above the MMP of the oil samples; the MMP for Cottonwood Creek crude oil with pure CO 2 at 60 o C is 2451 psi (Yang, et al, 2007). The WAG process is conducted in tertiary mode.…”

Section: Experimental Methods and Proceduresmentioning

confidence: 99%

Experimental Study on Optimum Half-Cycle Slug Size of Water Alternating Gas Under Tertiary Miscible Carbon Dioxide Flooding

2010

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The effect of half cycle slug size (HCSS) on Water Alternating Gas (WAG) performance in tertiary miscible carbon dioxide (CO 2 ) flooding is experimentally investigated. Different half cycle slug size influences the fluids mobility and the contact time between the injected fluids and oil, and hence to achieve the best possible displacement efficiency, an optimum water/gas half cycle slug size could exist and deserves investigation.Coreflood experiments are performed in Berea sandstone core, from which the WAG performance, such as percent oil recovery, tertiary recovery factor, and CO 2 utilization factor are determined. The core flooding experiments are conducted at 60 and at miscible condition, i.e., at a pressure 20% above the minimum miscible pressure (MMP) of the oil sample. The experiments utilize Cottonwood Creek crude oil and artificial brines. The injection and connate brine contain 33.33 wt% CaCl 2 and 66.67 wt% NaCl with salinities of 16000 ppm (mg/L) and 30000 ppm, respectively. In every core flood test, alternate cycles of brine and CO 2 with a WAG ratio of 1:1 are injected with half cycle slug size ranging from 0.05 to 0.75 PV.The results show that for the system of interest, the optimum HCSS is 0.1 PV, in which the CO 2 usage is only 0.6 PV to reach a high tertiary oil recovery of 40.63%. An HCSS higher or lower than 0.1 PV gives lower oil recovery. When HCSS is lower than 0.1 PV, the system gives lower oil recovery because some of the gas is trapped by water and keeps staying in the core instead of displacing oil. Meanwhile, an HCSS higher than 0.1 PV results in larger clusters of CO 2 and water, thus water inefficiently controls CO 2 mobility, which makes the CO 2 -oil contact time and interfacial area for mass transfer decrease and gas breakthrough occurs prematurely.This experimental study is an essential effort to obtain better understanding the effect of half cycle slug size on WAG performance, which has never been experimentally investigated before. The understanding is critical for optimizing the WAG performance.

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Section: Experimental Methods and Proceduresmentioning

confidence: 99%

Experimental Study on Optimum Half-Cycle Slug Size of Water Alternating Gas Under Tertiary Miscible Carbon Dioxide Flooding

2010

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“…Also reviewed were CO 2 sequestration source stream concentrations evaluated by other researchers; it was found that Koenen et al (2010) had selected two possible CO 2 streams for investigating the effects of impurities on geologic sequestration (see Table 12). Yang et al (2007) examined the effect of three different injection gases (pure CO 2 , impure CO 2 containing 5.19 mol % O 2 , and impure CO 2 containing 9.99 mol % O 2 ) on miscible CO 2 flooding. Yang et al (2007) found the minimum miscibility pressures for the tested oils increase unfavorably as the O 2 concentration in the CO 2 stream increased.…”

Section: Selection Of Co 2 Waste-stream Compositions For Use In Expermentioning

confidence: 99%

“…Yang et al (2007) examined the effect of three different injection gases (pure CO 2 , impure CO 2 containing 5.19 mol % O 2 , and impure CO 2 containing 9.99 mol % O 2 ) on miscible CO 2 flooding. Yang et al (2007) found the minimum miscibility pressures for the tested oils increase unfavorably as the O 2 concentration in the CO 2 stream increased.…”

Section: Selection Of Co 2 Waste-stream Compositions For Use In Expermentioning

confidence: 99%

Identification and Selection of Major Carbon Dioxide Stream Compositions

Schmick¹

2011

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A critical component in the assessment of long-term risk from geologic sequestration of carbon dioxide (CO 2 ) is the ability to predict mineralogical and geochemical changes within storage reservoirs as a result of rock-brine-CO 2 reactions. Impurities and/or other constituents in CO 2 source streams selected for sequestration can affect both the chemical and physical (e.g., density, viscosity, interfacial tension) properties of CO 2 in the deep subsurface. The nature and concentrations of these impurities are a function of both the industrial source(s) of CO 2 , as well as the carbon capture technology used to extract the CO 2 and produce a concentrated stream for subsurface injection and geologic sequestration.This report summarizes the relative concentrations of CO 2 and other constituents in exhaust gases from major non-energy-related industrial sources of CO 2 . Assuming that carbon capture technology would remove most of the incondensable gases N 2 , O 2 , and Ar, leaving SO 2 and NO x as the main impurities, the authors of this report selected four test fluid compositions for use in geochemical experiments. These included the following: 1) a pure CO 2 stream representative of food-grade CO 2 used in most enhanced oil recovery projects; 2) a test fluid composition containing low concentrations (0.5 mole %) SO 2 and NO x (representative of that generated from cement production); 3) a test fluid composition with higher concentrations (2.5 mole %) of SO 2 ; and 4) test fluid composition containing 3 mole % H 2 S. v

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“…The criterion indicating complete miscibility of the oil and gas is achievement of oil recovery higher than 90% for injection of 1.2 PV of the gas and the point when there is no more increase in the displacement efficiency as the injection pressure increases [14,15]. According to Fig.…”

Section: Pressure Mpamentioning

confidence: 99%

Improved Method for Calculating Minimum Miscibility Pressure for Gas Flooding

Hou

Luo

et al. 2015

Chem Technol Fuels Oils

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Minimum miscibility pressure (MMP) is a key parameter determining the feasibility of complete miscibility of oil and gas. Using a slim-tube model, we have experimentally established the MMP for gas and six oil samples. We propose an improved mathematical model for determining the MMP, designed using 97 groups of MMP data for hydrocarbons (18 groups for lean-gas flooding and 79 groups for rich-gas flooding). The model obtained is universal and is a function of the reservoir temperature, the average molecular weight of the C 7+ oil fraction, and the mole fraction of volatile components (CH 4 and N 2 ) and intermediate components (CO 2 , H 2 S, C 2 -C 6 ) in the crude oil and in the injected gas. We compare our proposed model with widely used empirical models, showing considerable convergence between the experimental data and the calculations; the percentage average absolute relative error (%AARE) is 7.11%.

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Effect of Oxygen on Minimum Miscibility Pressure in Carbon Dioxide Flooding

Cited by 23 publications

References 24 publications

Experimental Study on Optimum Half-Cycle Slug Size of Water Alternating Gas Under Tertiary Miscible Carbon Dioxide Flooding

Experimental Study on Optimum Half-Cycle Slug Size of Water Alternating Gas Under Tertiary Miscible Carbon Dioxide Flooding

Identification and Selection of Major Carbon Dioxide Stream Compositions

Improved Method for Calculating Minimum Miscibility Pressure for Gas Flooding

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