Experimental and theoretical investigation of gas/oil relative permeability hysteresis under low oil/gas interfacial tension and mixed-wet conditions

Seyyed Mobeen Fatemi, Mehran Sohrabi Sedeh, Mahmoud Jamiolahmady, Shaun Ireland

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Abstract

Accurate determination of relative permeability values and their hysteresis is crucial for obtaining a reliable prediction of the performance of water-alternating-gas (WAG) injection in oil reservoirs. In this paper, we report two series of gas/oil relative permeability curves obtained from coreflood experiments carried out in a mixed-wet core under a very low oil/gas interfacial tension (IFT) of 0.04 mN·m–1. The first set of the corefloods began by gas injection (drainage) in the core saturated with oil and immobile water (Swi). This was followed by a period of oil injection (imbibition), and this sequential injection of gas and oil continued, and in total, three drainage and two imbibition periods were carried out. In the second series of experiments, the core was initially saturated with gas and immobile water, and the experiment started with oil injection and followed by cycles of drainage and imbibitions. The measured pressure drop and production data were history matched through simulation analysis to obtain krg and kro values for each of the imbibition and drainage cycles. The results show that both the oil and the gas relative permeability curves show cycle-dependent hysteresis despite the very low gas/oil IFT. Therefore, the current assumption in existing models (such as Land, Carlson, and Killough) that the drainage scanning kr curves follow the preceding imbibition curve is not supported by our coreflood experiments. When compared to our measured data, the Carlson model predictions for krg in imbibition direction are poor. The Killough model predictions underestimate krg and overestimate kro, especially near trapped gas saturation regions. Beattie et al. hysteresis model is able to capture the krg and kro behavior that we observed in our experiments qualitatively, but it is still unable to predict the value of the observed hysteresis. The results suggest that, for mixed-wet systems, it is necessary to consider irreversible hysteresis loops for both the wetting and nonwetting phases. Such capability currently does not exist in reservoir simulators because of a lack of appropriate predictive tools.
Original languageEnglish
Pages (from-to)4366-4382
Number of pages17
JournalEnergy and Fuels
Volume26
Issue number7
DOIs
Publication statusPublished - Jul 2012

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Gas oils
Surface tension
Hysteresis
Drainage
Gases
Experiments
Water
Hysteresis loops
Pressure drop
Wetting
Oils
Simulators
Scanning

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title = "Experimental and theoretical investigation of gas/oil relative permeability hysteresis under low oil/gas interfacial tension and mixed-wet conditions",
abstract = "Accurate determination of relative permeability values and their hysteresis is crucial for obtaining a reliable prediction of the performance of water-alternating-gas (WAG) injection in oil reservoirs. In this paper, we report two series of gas/oil relative permeability curves obtained from coreflood experiments carried out in a mixed-wet core under a very low oil/gas interfacial tension (IFT) of 0.04 mN·m–1. The first set of the corefloods began by gas injection (drainage) in the core saturated with oil and immobile water (Swi). This was followed by a period of oil injection (imbibition), and this sequential injection of gas and oil continued, and in total, three drainage and two imbibition periods were carried out. In the second series of experiments, the core was initially saturated with gas and immobile water, and the experiment started with oil injection and followed by cycles of drainage and imbibitions. The measured pressure drop and production data were history matched through simulation analysis to obtain krg and kro values for each of the imbibition and drainage cycles. The results show that both the oil and the gas relative permeability curves show cycle-dependent hysteresis despite the very low gas/oil IFT. Therefore, the current assumption in existing models (such as Land, Carlson, and Killough) that the drainage scanning kr curves follow the preceding imbibition curve is not supported by our coreflood experiments. When compared to our measured data, the Carlson model predictions for krg in imbibition direction are poor. The Killough model predictions underestimate krg and overestimate kro, especially near trapped gas saturation regions. Beattie et al. hysteresis model is able to capture the krg and kro behavior that we observed in our experiments qualitatively, but it is still unable to predict the value of the observed hysteresis. The results suggest that, for mixed-wet systems, it is necessary to consider irreversible hysteresis loops for both the wetting and nonwetting phases. Such capability currently does not exist in reservoir simulators because of a lack of appropriate predictive tools.",
author = "Fatemi, {Seyyed Mobeen} and {Sohrabi Sedeh}, Mehran and Mahmoud Jamiolahmady and Shaun Ireland",
year = "2012",
month = "7",
doi = "10.1021/ef300386b",
language = "English",
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pages = "4366--4382",
journal = "Energy and Fuels",
issn = "0887-0624",
publisher = "American Chemical Society",
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TY - JOUR

T1 - Experimental and theoretical investigation of gas/oil relative permeability hysteresis under low oil/gas interfacial tension and mixed-wet conditions

AU - Fatemi, Seyyed Mobeen

AU - Sohrabi Sedeh, Mehran

AU - Jamiolahmady, Mahmoud

AU - Ireland, Shaun

PY - 2012/7

Y1 - 2012/7

N2 - Accurate determination of relative permeability values and their hysteresis is crucial for obtaining a reliable prediction of the performance of water-alternating-gas (WAG) injection in oil reservoirs. In this paper, we report two series of gas/oil relative permeability curves obtained from coreflood experiments carried out in a mixed-wet core under a very low oil/gas interfacial tension (IFT) of 0.04 mN·m–1. The first set of the corefloods began by gas injection (drainage) in the core saturated with oil and immobile water (Swi). This was followed by a period of oil injection (imbibition), and this sequential injection of gas and oil continued, and in total, three drainage and two imbibition periods were carried out. In the second series of experiments, the core was initially saturated with gas and immobile water, and the experiment started with oil injection and followed by cycles of drainage and imbibitions. The measured pressure drop and production data were history matched through simulation analysis to obtain krg and kro values for each of the imbibition and drainage cycles. The results show that both the oil and the gas relative permeability curves show cycle-dependent hysteresis despite the very low gas/oil IFT. Therefore, the current assumption in existing models (such as Land, Carlson, and Killough) that the drainage scanning kr curves follow the preceding imbibition curve is not supported by our coreflood experiments. When compared to our measured data, the Carlson model predictions for krg in imbibition direction are poor. The Killough model predictions underestimate krg and overestimate kro, especially near trapped gas saturation regions. Beattie et al. hysteresis model is able to capture the krg and kro behavior that we observed in our experiments qualitatively, but it is still unable to predict the value of the observed hysteresis. The results suggest that, for mixed-wet systems, it is necessary to consider irreversible hysteresis loops for both the wetting and nonwetting phases. Such capability currently does not exist in reservoir simulators because of a lack of appropriate predictive tools.

AB - Accurate determination of relative permeability values and their hysteresis is crucial for obtaining a reliable prediction of the performance of water-alternating-gas (WAG) injection in oil reservoirs. In this paper, we report two series of gas/oil relative permeability curves obtained from coreflood experiments carried out in a mixed-wet core under a very low oil/gas interfacial tension (IFT) of 0.04 mN·m–1. The first set of the corefloods began by gas injection (drainage) in the core saturated with oil and immobile water (Swi). This was followed by a period of oil injection (imbibition), and this sequential injection of gas and oil continued, and in total, three drainage and two imbibition periods were carried out. In the second series of experiments, the core was initially saturated with gas and immobile water, and the experiment started with oil injection and followed by cycles of drainage and imbibitions. The measured pressure drop and production data were history matched through simulation analysis to obtain krg and kro values for each of the imbibition and drainage cycles. The results show that both the oil and the gas relative permeability curves show cycle-dependent hysteresis despite the very low gas/oil IFT. Therefore, the current assumption in existing models (such as Land, Carlson, and Killough) that the drainage scanning kr curves follow the preceding imbibition curve is not supported by our coreflood experiments. When compared to our measured data, the Carlson model predictions for krg in imbibition direction are poor. The Killough model predictions underestimate krg and overestimate kro, especially near trapped gas saturation regions. Beattie et al. hysteresis model is able to capture the krg and kro behavior that we observed in our experiments qualitatively, but it is still unable to predict the value of the observed hysteresis. The results suggest that, for mixed-wet systems, it is necessary to consider irreversible hysteresis loops for both the wetting and nonwetting phases. Such capability currently does not exist in reservoir simulators because of a lack of appropriate predictive tools.

U2 - 10.1021/ef300386b

DO - 10.1021/ef300386b

M3 - Article

VL - 26

SP - 4366

EP - 4382

JO - Energy and Fuels

JF - Energy and Fuels

SN - 0887-0624

IS - 7

ER -