An experimental investigation of wettability alteration during CO2 immiscible flooding

Almutairi, Saad; Abu-Khamsin, Sidqi A.; Okasha, Taha; Aramco, Saudi; Hossain, Mohammed Kamal

doi:10.1016/j.petrol.2014.05.008

Cited by 24 publications

(14 citation statements)

References 15 publications

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“…Despite the mentioned subject, the process leading to IFT reduction by CO 2 dissolution can be of benefit to oil recovery, because it may lead to the in situ formation of brine‐in‐oil emulsions and further enhance oil recovery . CWF has also shown to alter wettability toward water‐wet condition, which is supported by micromodel observations, contact angle measurements, and results of spontaneous imbibition tests . As concluded from contact angle measurements and spontaneous imbibition results, wettability alteration by carbonated water (CW) has a much stronger effect on aged rock surfaces compared to un‐aged ones, while the highest alteration was reported for carbonate surfaces, which also went through dissolution by CW.…”

Section: Introductionmentioning

confidence: 89%

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

et al. 2017

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The rapid escalation of anthropogenic CO2 emissions at the same time as the growth in energy demand has brought the importance of CO2 enhanced oil recovery (EOR) into the spotlight. Nevertheless, fundamental problems with conventional CO2 injection have paved the way for practicing other strategies, such as carbonated waterflooding (CWF), i.e., flooding of CO2 dissolved in flood water through the reservoir. In this work, performance of CWF as a joint method of EOR and CO2 storage in an Iranian oil field is examined through sets of coreflooding experiments, conducted at a specified pressure and temperature condition on two different reservoir oil (light and heavy) and rock (carbonate and sandstone) samples from the investigated oil field. In summary, CWF improved the oil recovery as compared to waterflooding (WF). Average recovery factors (RFs) for CWG ranged from 6.4% to 13.6% when implemented as a secondary recovery technique and 4.2% to 4.8% when used as a tertiary recovery technique. This improvement was also higher in the carbonate rock than in the sandstone one, slightly higher with light oil than with heavy oil, and lower when a more saline brine was used for carbonated water preparation. CWF also showed to be more effective when implemented in a mixed‐wet system than in a water‐wet one. Moreover, considerable amounts (about 42‒60%) of the CO2 injected through the flooding brine were ultimately stored in the porous media. Finally, a co‐optimizing function was used as a standard for coupling CO2 EOR and storage. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Introductionmentioning

confidence: 89%

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

et al. 2017

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“…They reported less water wetting upon increasing the pressure in both systems. On the other hand, Al-Mutairi et al 32 compared the wetting of dead oil on an aged carbonate sample in carbonated synthetic brine at two different CO 2 concentrations against exposure time. They observed that increasing the CO 2 concentration in the brine resulted in a more pronounced water wetting.…”

Section: Introductionmentioning

confidence: 99%

Driving Mechanisms in CO₂-Assisted Oil Recovery from Organic-Rich Shales

Samara

Jaeger

2021

Energy Fuels

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Shales are currently regarded as potential hydrocarbon resources. At the same time, utilization of carbon dioxide (CO2) in enhanced oil recovery applications is being brought to the forefront worldwide. This necessitates that the mechanisms of oil recovery using CO2 are well understood. In this study, the wettability alteration and volumetric expansion upon CO2 injection into a system comprising organic-rich shale, water, and a model oil is investigated. Captive bubble tests performed at 0.1, 10, and 15 MPa and 60 °C using different aqueous phase compositions reveal that the shale is water wet under atmospheric pressure. Additionally, it is found that CO2 has an in situ aging effect that leads to reduced surface water wetting due to the expulsion of hydrocarbons from organic matter pores. This aging effect is in direct proportion to the CO2 pressure applied. Further, at elevated pressures, divalent ions promote a reduction in water wetness, while monovalent ions have less effect. Similar to contact angle measurements, the volumetric expansion is found to increase with pressure. The solubility of CO2 in the oil phase at 10 and 15 MPa is estimated to be around 20 and 28%, respectively.

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“…used sandstone cores (permeability of 89 md and porosity of 20%) in order to investigate capillary interactions between CO 2 liberated from CW and the crude oil. Al‐Mutairi et al . found that by dissolving CO 2 in brine, wettability changes from oil wet to intermediate wet.…”

Section: Introductionmentioning

confidence: 99%

“…Alizadeh et al 23 used sandstone cores (permeability of 89 md and porosity of 20%) in order to investigate capillary interactions between CO 2 liberated from CW and the crude oil. Al-Mutairi et al 24 found that by dissolving CO 2 in brine, wettability changes from oil wet to intermediate wet. Mat Ali et al 25 observed that when the concentration of carbonic acid increases in the system, wettability of sandpacks changes to more water wet.…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of smart carbonated water injection method in carbonates

2020

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Enhanced oil recovery (EOR) has been noticed during recent years from reservoirs that are at the end of their life plateau or in which production has been declined. Two of these EOR methods are as follows: carbonated water and smart water injection. In carbonated water injection method, CO2‐contained water is injected in reservoirs in order to decrease free CO2 injection mobility, increase water viscosity, and store/remove produced greenhouse CO2 gas safely, and in smart water injection method, the ions in brine are modified in order to make controlled reactions with distributed ions on the surface of rock to cause more hydrocarbon recovery. In this paper, the combination of these two methods is investigated as hybrid smart carbonated water injection to find out the recovery factor change and effective mechanisms. Experimental core flooding setup is used for investigation of hybrid EOR injection applicability and mechanisms. Probable mechanisms are measured using different cores and five water samples are used for preparing carbonated water (at pressure of 2500 psi) including sea water (34 261 ppm), river water (1329 ppm), one of Iranian reservoir formation water (FW) (163 711 ppm), 10 times diluted FW (0.1 FW), and 100 times diluted FW (0.01 FW). The effect of both brine content and volume of CO2 is determined during hybrid EOR assessment. The main mechanisms activated including pH variation, oil swelling, oil viscosity reduction, ion concentration variation in brine and porous media, and wettability alteration have been investigated. Hybrid method resulted in highest recovery (70%) mainly due to ion exchange, wettability alteration, oil swelling, and permeability enhancement. In addition, type of salt concentration will affect recovery as 0.01 FW results in 8% and 16% additional oil recovery compared to sea and river waters, respectively. Coupling of CO2 and salts will increase recovery factor due to mechanisms activated by each of these factors as 0.01 FW results in 10% more oil recovery compared to FW. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd.

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An experimental investigation of wettability alteration during CO2 immiscible flooding

Cited by 24 publications

References 15 publications

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

Driving Mechanisms in CO₂-Assisted Oil Recovery from Organic-Rich Shales

Experimental investigation of smart carbonated water injection method in carbonates

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An experimental investigation of wettability alteration during CO2 immiscible flooding

Cited by 24 publications

References 15 publications

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO2 storage

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO2 storage

Driving Mechanisms in CO2-Assisted Oil Recovery from Organic-Rich Shales

Experimental investigation of smart carbonated water injection method in carbonates

Contact Info

Product

Resources

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Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

Driving Mechanisms in CO₂-Assisted Oil Recovery from Organic-Rich Shales