Low-salinity-based enhanced oil recovery literature review and associated screening criteria

Chavan, Mukul; Dandekar, Abhijit; Patil, Shirish; Khataniar, Santanu

doi:10.1007/s12182-019-0325-7

Cited by 55 publications

(20 citation statements)

References 79 publications

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“…Zhang et al also observed improved oil recovery (e.g., up to 13% original oil in place) from their laboratory studies at lower salinity, i.e., 1500 ppm of injection brine. The mechanism of the LSWI was not very well understood, but wettability alteration and IFT reduction were considered as key factors for improved oil recovery by the majority of the researchers. ,,− …”

Section: Introductionmentioning

confidence: 99%

Nanofluids of Kaolinite and Silica in Low Saline Seawater (LowSal) with and without Surfactant: Interfacial Tension and Wettability Alteration of Oil–Water–Rock System for Low Salinity-Enhanced Oil Recovery

Behera

Sangwai

2020

Ind. Eng. Chem. Res.

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Low salinity water injection (LSWI) has gained popularity recently as a potential enhanced oil recovery (EOR) method. The efficiency of LSWI can be improved with the advent of nanotechnology. Nanofluids can alter the wettability of the solid surface from intermediate-wet to water-wet, a condition most favorable to enhance the oil displacement efficiency. Studies have been reported in the literature on the use of nanoparticles and surfactants with LSWI mainly for carbonate rock and synthesized saline water containing mainly sodium salt; however, not much information is available for sandstone rock and the use of low saline seawater (LowSal). Also, a comparative study on the use of silica and kaolinite nanofluids in LowSal has not yet been explored in detail to understand their impact on the wettability alteration and interfacial tension (IFT) of the oil−nanofluid−rock system. Thus, in this work, silica and kaolinite nanofluids have been prepared in LowSal with varying concentrations (0−2000 ppm) without and with an anionic surfactant, dioctyl sodium sulfosuccinate (AOT), to assess their impact on the IFT and wettability alternation (through contact angle measurements) of the oil−nanofluid−rock system. Three different oil samples, viz., model oil A, model oil B, and light crude oil to represent acidic, basic, and weakly basic oil systems, respectively, have been considered. An intermediate-wet quartz plate is used to mimic the properties of the sandstone rock. A detailed mechanism has been highlighted to ascertain the impact of nanofluids on the IFT and wettability alteration of the representative rock sample from an intermediate-wet to water-wet condition based on the Gibbs adsorption isotherm, scanning electron microscopy (SEM), and energy-dispersive X-ray (EDXA/EDS/EDX) studies. The results are outlined to understand the possible future applications of silica and kaolinite nanofluids for enhanced oil recovery processes.

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Section: Introductionmentioning

confidence: 99%

Nanofluids of Kaolinite and Silica in Low Saline Seawater (LowSal) with and without Surfactant: Interfacial Tension and Wettability Alteration of Oil–Water–Rock System for Low Salinity-Enhanced Oil Recovery

Behera

Sangwai

2020

Ind. Eng. Chem. Res.

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“…While the mechanisms of LSWF to increase oil recovery have not been verified completely yet, the laboratory core floods and field tests have shown that rock/fluid interactions as well as the solution and surface chemistry play important roles [13][14][15][16][17]. It is widely agreed that the EOR by LSWF is related to wettability alteration toward more water wet conditions [18,19], which creates positive capillary forces and increases the microscopic sweep efficiency in heterogeneous pore systems [19].…”

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confidence: 99%

Dynamic wettability alteration for combined low salinity brine injection and surfactant flooding on silica surface

et al. 2020

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Experimental results of dynamic contact angle measurements of low salinity brine and combined low salinity water and surfactant flooding (LSW-SF) on silica surface are presented in this study. Dynamic contact angle experiments were carried out for four crude oil samples with low salinity brines and combined low salinity and sodium dodecylbenzene sulfonate (SDBS) solutions. Similar measurements with the same ion strength in presence of different cations, Na + and Ca 2+ , for low salinity injections and combined low salinity-SDBS solutions were also carried out to study the change in dynamic contact angles and wetting behavior. The presences of different cations change the initial contact angles in low salinity solution injections and show different dynamic behaviors in presence of different crude oils. The signs and values of the line tension to oil/water interfacial tension ratios have been calculated from the size dependence of the dynamic contact angle measurements on the silica coated quartz crystal microbalance sensors. Analysis indicates positive line tension values for low salinity brine systems and negative values for LSW-SF systems. Injection of surfactant solutions in presence of electrolyte prompts the spreading of the oil droplet over the surface, which is induced by interfacial tension gradient from the top of the oil droplet toward the contact line. The results indicated that spreading time, which is the required time for oil drop to gradually flatten out, is dependent on type of electrolytes and is a function of surface excess concentration of the surfactant.

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“…In explaining the production mechanisms during low-salinity water-flooding (LSWF), Chavan et al 40 argued that multicomponent ion exchange (MIE) plays a key role. MIE first expands and opens up the outer diffuse layer, and then monovalent ions within the injecting phase replace the divalent ions of the adsorption layer.…”

Section: Resultsmentioning

confidence: 99%

Formation Damage Induced by Water-Based Alumina Nanofluids during Enhanced Oil Recovery: Influence of Postflush Salinity

et al. 2020

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Injecting nanofluids (NFs) has been proven to be a potential method to enhance oil recovery. Stranded oil is produced by wettability alteration where nanoparticles form a wedge film on pore wall surfaces, which is thought to shrink the pore space of the reservoir. Furthermore, ensuring the stability of the injected NF during the application is a major challenge. A low permeability reservoir and salinity of water make the response of NF injection to the formation damage more difficult. This article, therefore, studied the formation damage induced by the injection of alumina nanofluids (Al-NFs) in a relatively low permeability (7.1 mD) sandstone core. The salinity of the postflush water was also considered to mitigate the destructive impact. Al-NF was formulated by dispersing alumina nanoparticles (Al-NPs) in an aqueous solution of sodium dodecylbenzene sulfonate (SDBS) at its critical micelle concentration (CMC, 0.1 wt %). The formation damage, inherent to Al-NF injection, was evaluated by core-flooding tests. The assays consisted of the injection of 1 PV Al-NF (0.05 wt %) at the trail of which postflush at different salinities was flooded. The study found that the salinity of the postflush has an effect on the formation damage and oil recovery factor (RF). A chase water with a salinity concentration of 3 wt % sodium chloride (NaCl) produced an RF of 8.7% compared to a base case of water-flooding with a pressure drop of up to 13 MPa across the core (70 mm in length). These results pertained to the deposition of Al-NPs at the injection end. However, lowering the postflush salinity to 1 wt % NaCl mitigated the formation damage as evidenced by the decrease in pressure (35%) and an increase in RF to 17.2%.

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Low-salinity-based enhanced oil recovery literature review and associated screening criteria

Cited by 55 publications

References 79 publications

Nanofluids of Kaolinite and Silica in Low Saline Seawater (LowSal) with and without Surfactant: Interfacial Tension and Wettability Alteration of Oil–Water–Rock System for Low Salinity-Enhanced Oil Recovery

Nanofluids of Kaolinite and Silica in Low Saline Seawater (LowSal) with and without Surfactant: Interfacial Tension and Wettability Alteration of Oil–Water–Rock System for Low Salinity-Enhanced Oil Recovery

Dynamic wettability alteration for combined low salinity brine injection and surfactant flooding on silica surface

Formation Damage Induced by Water-Based Alumina Nanofluids during Enhanced Oil Recovery: Influence of Postflush Salinity

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