Parametric study of oil recovery during CO2 injections in fractured chalk: Influence of fracture permeability, diffusion length and water saturation

Fernø, Martin A.; Steinsbø, Marianne; Eide, Øyvind; Ahmed, Abdelazim Abbas; Ahmed, Kamran; Graue, A.

doi:10.1016/j.jngse.2015.09.052

Cited by 32 publications

(8 citation statements)

References 21 publications

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“…In contrast, oil recovery from fractured systems was identified by: 1) a rapid breakthrough of CO2 before 0.05PV injected, where most of the oil was produced after CO2-breakthrough, 2) a low production rate from the onset of CO2 injection, 3) a long tail production and 4) no differential pressure across the core length, which indicated recovery by diffusion. This corroborates previous results in chalk (Eide et al, 2015b;Fernø et al, 2015).…”

Section: Co2 Injection In Edwards Limestonesupporting

confidence: 93%

Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations

Fernø

Eide

Steinsbø

et al. 2015

Journal of Petroleum Science and Engineering

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Section: Co2 Injection In Edwards Limestonesupporting

confidence: 93%

Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations

Fernø

Eide

Steinsbø

et al. 2015

Journal of Petroleum Science and Engineering

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“…Compared with sandstone, the contact angle of shale has greatly increased after CO 2 soaking, and the contact angle of Y1 and Y2 shale has increased by 19.27% and 36.80%, respectively. This is mainly because the microstructure and chemical composition of shale surface have changed after CO 2 soaking, which affects the contact angle of shale [11,15]. Compared with liquid CO 2 , the wettability of supercritical CO 2 on sandstone and shale is more significant, mainly due to its smaller interfacial tension and stronger diffusion capacity [8,12].…”

Section: The Results and Analysismentioning

confidence: 99%

“…Since supercritical carbon dioxide has the characteristics of high density, low viscosity, high diffusivity and no damage to the reservoir [8], it can effectively reduce the formation fracture pressure and efficiently replace methane [9,10]. CO 2 geological storage is carried out while enhancing the development of shale gas, so as to finally realize low-carbon, clean and efficient development of shale gas [11,12]. Especially under the background of "carbon neutralization" and "carbon peaking", the enhanced development of shale oil and gas by CO 2 and the geological storage of CO 2 have become a worldwide research hotspot [13,14].…”

Section: Introductionmentioning

confidence: 99%

Experimental study of the effect of CO₂ on rock seepage characteristics

Xia

Sun

Liu

et al. 2023

IOP Conf. Ser.: Earth Environ. Sci.

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The influence of different phase states of CO2 on the seepage characteristics of different rocks is one of the most important factors to enhance shale gas exploitation, such as CO2 fracturing and displacement, and achieve CO2 geological storage. Rock soaking experiments with different CO2 phase states were carried out to compare and analyze the influence of permeability, contact angle, starting pressure gradient and other seepage characteristic parameters of sandstone and shale before and after soaking. Research shows: After soaking in liquid and supercritical CO2, the permeability and contact angle of sandstone and shale increase in varying degrees, and the starting pressure gradient decreases in varying degrees. After soaking in liquid CO2, the permeability of sandstone and shale increased by 1.71% and 12.88% respectively, the contact angle increased by 3.23% and 7.47% respectively, and the starting pressure gradient decreased by 3.02% and 5.88% respectively. After supercritical CO2 immersion, the permeability of sandstone and shale increased by 37.37% and 48.82% respectively, the contact angle increased by 19.27% and 36.80% respectively, and the starting pressure gradient decreased by 35.39% and 39.34% respectively. Compared with sandstone, the seepage characteristics of shale after soaking in liquid and supercritical CO2 have greater changes; Compared with liquid CO2, the seepage characteristics of sandstone and shale change more after supercritical CO2 soaking. With the increase of supercritical CO2 soaking time, the contact angle of sandstone slightly increases, while that of shale obviously increases. Compared with liquid CO2, the change of seepage curves of sandstone and shale after supercritical CO2 soaking is more different.

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“…Thus, diffusion dominated oil recovery above that of viscous displacement by foam at FCM conditions. CO2 diffusion is a dominant recovery mechanism at core-scale with the potential to recover nearly 100% of the oil [34,35]. At constant fg = 0.70, CO2 diffusion recovered the same amount of oil regardless of injection mode, on average 29.7 ± 2.2% OOIP.…”

Section: Co2 Foam Eor 431 First-contact Miscible Conditionsmentioning

confidence: 96%

Core-scale sensitivity study of CO₂ foam injection strategies for mobility control, enhanced oil recovery, and CO₂ storage

et al. 2020

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This paper presents experimental and numerical sensitivity studies to assist injection strategy design for an ongoing CO2 foam field pilot. The aim is to increase the success of in-situ CO2 foam generation and propagation into the reservoir for CO2 mobility control, enhanced oil recovery (EOR) and CO2 storage. Un-steady state in-situ CO2 foam behavior, representative of the near wellbore region, and steady-state foam behavior was evaluated. Multi-cycle surfactant-alternating gas (SAG) provided the highest apparent viscosity foam of 120.2 cP, compared to co-injection (56.0 cP) and single-cycle SAG (18.2 cP) in 100% brine saturated porous media. CO2 foam EOR corefloods at first-contact miscible (FCM) conditions showed that multi-cycle SAG generated the highest apparent foam viscosity in the presence of refined oil (n-Decane). Multi-cycle SAG demonstrated high viscous displacement forces critical in field implementation where gravity effects and reservoir heterogeneities dominate. At multiple-contact miscible (MCM) conditions, no foam was generated with either injection strategy as a result of wettability alteration and foam destabilization in presence of crude oil. In both FCM and MCM corefloods, incremental oil recoveries were on average 30.6% OOIP regardless of injection strategy for CO2 foam and base cases (i.e. no surfactant). CO2 diffusion and miscibility dominated oil recovery at the core-scale resulting in high microscopic CO2 displacement. CO2 storage potential was 9.0% greater for multi-cycle SAGs compared to co-injections at MCM. A validated core-scale simulation model was used for a sensitivity analysis of grid resolution and foam quality. The model was robust in representing the observed foam behavior and will be extended to use in field scale simulations.

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Parametric study of oil recovery during CO2 injections in fractured chalk: Influence of fracture permeability, diffusion length and water saturation

Cited by 32 publications

References 21 publications

Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations

Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations

Experimental study of the effect of CO₂ on rock seepage characteristics

Core-scale sensitivity study of CO₂ foam injection strategies for mobility control, enhanced oil recovery, and CO₂ storage

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Parametric study of oil recovery during CO2 injections in fractured chalk: Influence of fracture permeability, diffusion length and water saturation

Cited by 32 publications

References 21 publications

Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations

Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations

Experimental study of the effect of CO2 on rock seepage characteristics

Core-scale sensitivity study of CO2 foam injection strategies for mobility control, enhanced oil recovery, and CO2 storage

Contact Info

Product

Resources

About

Experimental study of the effect of CO₂ on rock seepage characteristics

Core-scale sensitivity study of CO₂ foam injection strategies for mobility control, enhanced oil recovery, and CO₂ storage