Capillary pressure and relative permeability estimation for low salinity waterflooding processes using pore network models

Martínez-Mendoza, Edgar G.; Díaz-Viera, Martín A.; Coronado, M.; Mendoza-Rosas, Ana Teresa

doi:10.1016/j.petrol.2019.106253

Cited by 14 publications

(9 citation statements)

References 52 publications

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“…The recovery rate was calculated by determining the ratio of the curve envelope area of the T 2 spectrum to the saturated oil curve, and the recovery rates of FW, LSW, LSW-0.2Ca 2+ , LSW-0.5Ca 2+ , and LSW-0.5Ca 2+ -3SO 4 2– were 29.36, 34.32, 37.31, and 39.57%, respectively. The decrease in the T 2 peak was found to be associated with changes in intrapore wettability and capillary force. , Decreasing the salinity of the injected water and the mass concentration of Ca 2+ and increasing the mass concentration of SO 4 2– led to a more water-wettable rock surface, resulting in a thicker water film on the rock surface. Tight reservoirs have a low porosity and poor permeability, leading to greater resistance to fluid migration.…”

Section: Resultsmentioning

confidence: 91%

“…This alteration in wettability results in a corresponding change in capillary pressure. , Under the effect of the capillary force, the self-absorption phenomenon of hydrophilic rock can efficiently expel the crude oil from the pore space. The viscosity finger within the core is decreased, enhancing sweep efficiency and in turn, enhancing the recovery rate. , When the divalent cation concentration in the water decreases, the polar components bridged to the surface of the rock become detached, resulting in water-wetness. This is demonstrated in ion exchange reactions and , which are the processes of binding carboxylate groups to the rock surface and can also represent the process of detachment of carboxylate from the rock surface due to decreasing ion concentration.…”

Section: Discussionmentioning

confidence: 99%

“…When the wettability changes, the crude oil molecules that were originally adsorbed on the rock surface become detached. This alteration in wettability results in a corresponding change in capillary pressure. , Under the effect of the capillary force, the self-absorption phenomenon of hydrophilic rock can efficiently expel the crude oil from the pore space. The viscosity finger within the core is decreased, enhancing sweep efficiency and in turn, enhancing the recovery rate. , When the divalent cation concentration in the water decreases, the polar components bridged to the surface of the rock become detached, resulting in water-wetness.…”

Section: Discussionmentioning

confidence: 99%

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Experimental Study on the Mechanism and Law of Low-Salinity Water Flooding for Enhanced Oil Recovery in Tight Sandstone Reservoirs

Fan,

Liu,

et al. 2024

ACS Omega

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Currently, research surrounding low-salinity water flooding predominantly focuses on medium-to high-permeability sandstone reservoirs. Nevertheless, further investigation is necessary to implement this technique with regard to tight sandstone reservoirs. The present study comprises a series of experiments conducted on the crude oil and core of the Ordos Chang 6 reservoir to investigate the influence of ionic composition on low-salinity water flooding in tight oil reservoirs. The change in wettability on the rock surface was analyzed by using the contact angle experiment. The change in recovery rate was analyzed using a core displacement experiment. The reaction between rock fluids was analyzed using an ion chromatography experiment. Additionally, a nuclear magnetic resonance (NMR) experiment was used to analyze the mobilization law of crude oil and the change in wettability on the scale of the rock core. This led to a comprehensive discussion of the law and mechanism of enhancing the recovery rate via low-salinity water flooding from various perspectives. Experiments show that low-salinity water flooding is an effective technique for enhancing recovery in tight sandstone reservoirs. Altering the ionic composition of injected water can improve the water wettability of the rock surface and enhance recovery. Decreasing the mass concentration of Ca 2+ or increasing the mass concentration of SO 4 2− can prompt the ion-exchange reaction on the rock surface and detachment of polar components from the surface. Consequently, the wettability of the rock surface strengthens, augmenting the recovery process. Nuclear magnetic resonance experiments evidence that low-salinity water injection, with ion adjustment, significantly alters the interactions between the rock and fluid in tight sandstone reservoirs. As a result, the T 2 signal amplitude decreases significantly, residual oil saturation reduces considerably, and the hydrophilic nature of the rock surface increases.

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Section: Resultsmentioning

confidence: 91%

Section: Discussionmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

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Experimental Study on the Mechanism and Law of Low-Salinity Water Flooding for Enhanced Oil Recovery in Tight Sandstone Reservoirs

Fan,

Liu,

et al. 2024

ACS Omega

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“…The differences between these algorithms are based on different pore space characterization and pore size assignment methods. The output pore network is then used to conduct flow simulations and to investigate different processes such as wettability, multiphase flow, reactive transport, and no-Darcy flow [20][21][22][23][24][25].…”

Section: Introductionmentioning

confidence: 99%

Pore-Scale Characterization and PNM Simulations of Multiphase Flow in Carbonate Rocks

et al. 2021

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This paper deals with pore-scale two-phase flow simulations in carbonate rock using the pore network method (PNM). This method was used to determine the rock and flow properties of three different rock samples, such as porosity, capillary pressure, absolute permeabilities, and oil–water relative permeabilities. The pore network method was further used to determine the properties of rock matrices, such as pore size distribution, topological structure, aspect ratio, pore throat shape factor, connected porosity, total porosity, and absolute permeability. The predicted simulation for the network-connected porosity, total porosity, and absolute permeability agree well with those measured experimentally when the image resolution is appropriate to resolve the relevant pore and throat sizes. This paper also explores the effect of the wettability and fraction of oil-wet pores on relative permeabilities, both in uniform and mixed wet systems.

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“…Various impacts of low salinity corefloods were observed on both sandstone and carbonate samples, such as wettability alteration, a reduction in residual oil saturation, and interfacial tension (e.g., [18][19][20][21][22]). This impact has been attributed to the chemical interactions between the injected low salinity brine, crude oil, and rock surfaces.…”

Section: Introductionmentioning

confidence: 99%

Using Low Salinity Waterflooding to Improve Oil Recovery in Naturally Fractured Reservoirs

et al. 2020

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Low salinity waterflooding is an effective technique to accelerate and boost oil recovery. The impact of this technique has been investigated widely in laboratories for various scales and rock typing, most of which have demonstrated a potential improvement in oil recovery. This improvement has been attributed to several chemical and physical interactions that led to a change in the wettability to become more water-wet, as well as a reduction in the residual oil saturation. Meanwhile, it is rare to find a discussion in the literature about the efficiency of low salinity flooding in naturally fractured reservoirs. Therefore, in this work, we investigate the potential advantages of this method in fractured reservoirs using numerical simulations. A new approach to estimate the weighting factor using a tracer model has been proposed to determine the brine salinity and, hence, its properties in the mixing region. We have also used the relative permeability curves as a proxy for any physical and chemical mechanisms which are not represented explicitly in the model. The simulation outcomes highlighted the advantage of low salinity waterflooding in fractured reservoirs. An increment in oil recovery by 10.7% to 13% of Stock Tank Oil Initially In Place (STOIIP) was obtained using the dual- and single-porosity model, respectively. Therefore, the low salinity waterflooding technique represents a promising low-cost, effective method in fractured reservoirs.

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Capillary pressure and relative permeability estimation for low salinity waterflooding processes using pore network models

Cited by 14 publications

References 52 publications

Experimental Study on the Mechanism and Law of Low-Salinity Water Flooding for Enhanced Oil Recovery in Tight Sandstone Reservoirs

Experimental Study on the Mechanism and Law of Low-Salinity Water Flooding for Enhanced Oil Recovery in Tight Sandstone Reservoirs

Pore-Scale Characterization and PNM Simulations of Multiphase Flow in Carbonate Rocks

Using Low Salinity Waterflooding to Improve Oil Recovery in Naturally Fractured Reservoirs

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