Effects of gas relative permeability hysteresis and solubility on associated CO2 storage performance

Jin, Lu; Pekot, Lawrence J.; Smith, Steven A.; Salako, Olarinre; Peterson, Kyle J.; Bosshart, Nicholas W.; Hamling, John A.; Mibeck, Blaise A. F.; Hurley, John P.; Beddoe, Christopher J.; Gorecki, Charles D.

doi:10.1016/j.ijggc.2018.06.002

Effects of gas relative permeability hysteresis and solubility on associated CO₂ storage performance

Journal Article · Thu Jun 14 00:00:00 EDT 2018 · International Journal of Greenhouse Gas Control

DOI:https://doi.org/10.1016/j.ijggc.2018.06.002· OSTI ID:1874357

^[1]; Pekot, Lawrence J. ^[2]; Smith, Steven A. ^[2]; Salako, Olarinre ^[2]; Peterson, Kyle J. ^[2]; Bosshart, Nicholas W. ^[2]; Hamling, John A. ^[2]; Mibeck, Blaise A. F. ^[2]; Hurley, John P. ^[2]; Beddoe, Christopher J. ^[2]; Gorecki, Charles D. ^[2]

Univ. of North Dakota, Grand Forks, ND (United States); Univ. of North Dakota, Grand Forks, ND (United States). Energy & Environmental Research Center
Univ. of North Dakota, Grand Forks, ND (United States)

CO₂ enhanced oil recovery (EOR) has been carried out in the Bell Creek oil field since 2013. Together with the encouraging oil production results, a considerable quantity of CO₂ has also been trapped in the reservoir as a normal part of the EOR process, also referred to as associated storage. Because of the complex geologic conditions in the field, a series of experimental and modeling work have been conducted to better understand the CO₂ EOR and associated storage performance in the reservoir. Effects of gas relative permeability hysteresis and solubility on associated CO₂ storage performance are thoroughly investigated in this study. Here, a proportion of injected CO₂ remains behind through residual and solubility trapping mechanisms when CO₂ flows through a reservoir during a CO₂ EOR process. Over 50 core plugs were collected from the reservoir to characterize the rock properties. Mineralogical analysis and capillary pressure measurements showed that the mineral composition and pore-size distribution in the reservoir are favorable for residual trapping of CO₂. The hysteresis of gas relative permeability was measured to assess the effect of residual trapping on associated CO₂ storage using steady-state relative permeability tests and reservoir simulation. The reservoir oil was characterized based on pressure–volume–temperature experiments and Peng–Robinson equation of state modeling, which showed that CO₂ solubility in oil is much greater (≥5 times) than in water. Results indicated that depleted oil reservoirs have great potential to store a huge quantity of CO₂ associated with EOR operations, as residual oil saturation is 0.3 or greater in most conventional oil reservoirs after water flooding.

View Accepted Manuscript (DOE)

Research Organization:: Univ. of North Dakota, Grand Forks, ND (United States). Energy & Environmental Research Center

Sponsoring Organization:: USDOE; USDOE Office of Fossil Energy (FE)

Grant/Contract Number:: FC26-05NT42592

OSTI ID:: 1874357

Alternate ID(s):: OSTI ID: 1601319
OSTI ID: 1538342

Journal Information:: International Journal of Greenhouse Gas Control, Journal Name: International Journal of Greenhouse Gas Control Vol. 75; ISSN 1750-5836

Publisher:: ElsevierCopyright Statement

Country of Publication:: United States

Language:: English

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Related Subjects

02 PETROLEUM
54 ENVIRONMENTAL SCIENCES
58 GEOSCIENCES
Associated CO2 storage
CO2 enhanced oil recovery
PCOR
Plains Carbon Dioxide Reduction Partnership
Relative permeability hysteresis
Residual trapping
Solubility trapping

Effects of gas relative permeability hysteresis and solubility on associated CO2 storage performance

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References (39)

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Effects of gas relative permeability hysteresis and solubility on associated CO₂ storage performance