Impact of salinity and connate water on low salinity water injection in secondary and tertiary stages for enhanced oil recovery in carbonate oil reservoirs

Mohammadkhani, Samira; Shahverdi, Hamid Reza; Esfahany, Mohsen Nasr

doi:10.1088/1742-2140/aaae84

Cited by 37 publications

(19 citation statements)

References 28 publications

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“…Additional oil recovery was observed under injection of CaCO 3 saturated seawater, where the calcite dissolution was excluded. Mohammadkhani et al (2018) investigated the effect of connate water salinity and saturation, as well as of the injected brine salinity, by conducting five core floodings on limestone core plugs at the room temperature. It was concluded that de-dolomitization and anhydride precipitation were among the determining mechanisms.…”

Section: Observations Observations Observations Observations Of the Dissolution Of The Dissolution Of The Dissolution Of The Dissolutionmentioning

confidence: 99%

Mechanisms of smart waterflooding in carbonate oil reservoirs - A review

Hao

Mohammadkhani

Shahverdi

et al. 2019

Journal of Petroleum Science and Engineering

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111

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Section: Observations Observations Observations Observations Of the Dissolution Of The Dissolution Of The Dissolution Of The Dissolutionmentioning

confidence: 99%

Mechanisms of smart waterflooding in carbonate oil reservoirs - A review

Hao

Mohammadkhani

Shahverdi

et al. 2019

Journal of Petroleum Science and Engineering

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111

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“…Low-salinity water injection (LSWI) has shown improved oil recovery in both sandstone [1][2][3][4][5] and carbonate [6][7][8] reservoirs. Although the mechanisms behind the success of LSWI in carbonates have been studied extensively [9][10][11][12][13][14], decoupling the specific underlying mechanisms remains a challenge.…”

Section: Introductionmentioning

confidence: 99%

“…The effect of a modified brine on oil recovery from core samples is routinely investigated by forced imbibition (core flooding) experiments and is often supplemented by spontaneous imbibition tests [6,23,[32][33][34][35]. Spontaneous imbibition is governed primarily by capillary forces, while in forced imbibition experiments viscous forces prevail [36].…”

Section: Introductionmentioning

confidence: 99%

Crude Oil–Brine–Rock Interactions in Tight Chalk Reservoirs: An Experimental Study

et al. 2021

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We present a systematic study of crude oil–brine–rock interactions in tight chalk cores at reservoir conditions. Flooding experiments are performed on outcrops (Stevns Klint) as well as on reservoir core plugs from Dan field, the Ekofisk and Tor formations. These studies are carried out in core plugs with reduced pore volumes, i.e., short core samples and aged with a dynamic ageing method. The method was evaluated by three different oil compositions. A series of synthetic multicomponent brines and designed fluid injection scenarios are investigated; injection flow rates are optimized to ensure that a capillary-dominant regime is maintained. Changes in brine compositions and fluid distribution in the core plugs are characterized using ion chromatography and X-ray computed tomography, respectively. First, we show that polar components in the oil phase play a major role in wettability alteration during ageing; this controls the oil production behavior. We also show that, compared to seawater, both formation water and ten-times-diluted seawater are better candidates for enhanced oil recovery in the Dan field. Finally, we show that the modified flow zone indicator, a measure of rock quality, is likely the main variable responsible for the higher oil recoveries observed in Tor core samples.

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“…The effect of low salinity water injection on carbonate formation has not been thoroughly explained in contrast to sandstone rocks. The defective term presenting this deputation is thought to be wettability alteration by low salinity water with respect to clay components participation, which is not the case in carbonate rocks [5,8,[11][12][13][14][15]. Wettability alteration is the main challenge for enhanced oil recovery from carbonate reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of water composition and salinity effect on the oil recovery in carbonate reservoirs

Zaheri

Khalili

Sharifi

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Water injection has been known as a conventional approach employed for years in order to achieve higher oil recovery from oil reservoirs. Since the last decade many researchers conducted on the water injection assessment suggested that low salinity water flooding can be an effective flooding mechanism and it can be used as an enhanced oil recovery method. Several examinations were conducted to identify governing mechanisms entailed in oil extraction and the effect of salinity and different types of ionic contents contained in Formation Water (FW) and injected fluid. This study is dedicated to address the influence of salinity and different types of ionic contents contained in formation water and injected fluid on incremental oil recovery. For this purpose, fluid–fluid and rock–fluid interaction were investigated especially for evaluating the effect of calcium ions in the formation water and sulfate ions in the injected water. Several experiments were carried out including core-flooding, contact angle, and imbibition tests. While former researchers concluded that reducing the salinity of injected water causing a decrease in ionic strength may lead to a greater oil recovery, in this research, we showed that these statements are not necessarily true. It was observed that existence of the high calcium concentration in the formation water would cause significant effect on wettability status of rocks and final oil recovery during low salinity water injection. This process is mainly due to rock wettability alteration. Wettability alteration mechanism in carbonate rocks is explained through interaction between rock and fluid composition. The results indicate the decisive role of calcium ions in the formation water at all stages from aging in oil to primary and secondary recovery. In addition to that, it was observed that more sulfate ion concentration in the injected water enhances rock wettability alteration.

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Impact of salinity and connate water on low salinity water injection in secondary and tertiary stages for enhanced oil recovery in carbonate oil reservoirs

Cited by 37 publications

References 28 publications

Mechanisms of smart waterflooding in carbonate oil reservoirs - A review

Mechanisms of smart waterflooding in carbonate oil reservoirs - A review

Crude Oil–Brine–Rock Interactions in Tight Chalk Reservoirs: An Experimental Study

Experimental investigation of water composition and salinity effect on the oil recovery in carbonate reservoirs

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