Productivity index enhancement by wettability alteration in two-phase compressible flows

Naik, Saurabh; You, Zhenjiang; Bedrikovetsky, Pavel

doi:10.1016/j.jngse.2017.11.007

Cited by 30 publications

(17 citation statements)

References 35 publications

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“…However, there is not a universal functional form for capillary J-function and relative permeability curves. 44,45 For example, the following equations have been recommended for capillary pressure and nonwetting phase relative permeability 46…”

Section: Methodsmentioning

confidence: 99%

Analytical Exact Solution for Co-Current Spontaneous Imbibition in Porous Media Considering Early- and Late-Time Effects

et al. 2021

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Spontaneous imbibition (SI) of the wetting phase through the porous medium to displace the nonwetting phase is determined by capillary diffusion and injection fluid advection. This system is described using a transport equation of involved mechanisms and a pressure equation. The Buckley−Leverett solution is a particular case when capillary pressure is negligible. There are also analytical solutions available for cases with capillary diffusion as the dominant involved mechanism. In this study, a new mathematical model is developed to consider how both effects are significant. The model proposes an exact valid solution for both early-time (until the saturation front reaches effluent) and late-time imbibition. The accuracy of the model has been validated by comparing the suggested analytical model with numerical and experimental data. One of the advantages of the developed model is that despite the previous models, the injection rate does not need to be proportional to the square root of time, and other functional forms can be applied. Furthermore, the suggested analytical scheme is valid for strongly water-wet (SWW), weakly water-wet (WWW), and mixed-wet (MW) rock surfaces.

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Section: Methodsmentioning

confidence: 99%

Analytical Exact Solution for Co-Current Spontaneous Imbibition in Porous Media Considering Early- and Late-Time Effects

et al. 2021

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“…Developed countries such as the United States, China, and Europe have already addressed numerous apprehensions about the status and hurdles. They have also recommended practices for unconventional natural gas resource exploitation and development to solve the energy crisis via different enhanced oil and gas recovery pathways − and smart drilling techniques. − Figure shows the status of production of unconventional natural gas from coalbed methane, shale gas, and tight gas around the globe. , Among the developing countries, Pakistan needs considerable natural gas in order to develop its infrastructure. Surging energy consumption in different industry sectors such as power-generating plants and cement industry has also increased natural gas consumption.…”

Section: Introductionmentioning

confidence: 99%

Effect of Cryogenic Liquid Nitrogen on the Morphological and Petrophysical Characteristics of Tight Gas Sandstone Rocks from Kirthar Fold Belt, Indus Basin, Pakistan

et al. 2020

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Tight gas sandstone production faces enormous challenges from marginal matrix porosity and permeability in rock formations. In this regard, the liquid nitrogen (LN 2 ) treatment remedy has been suggested as an appropriate stimulation approach to resolve this issue. An experimental study was carried out to investigate the cryogenic liquid nitrogen fracturing of tight rock sandstone to enhance gas recovery from such reservoirs. Three core samples from the Kirthar fold belt were subjected to LN 2 treatment for 30, 60, and 90 min. Petrophysical characterization was performed through scanning electron microscopy, atomic force microscopy, nanoindentation measurements, and quantitative X-ray diffraction technique. The results reveal wide conductive fractures with an optimum size of 30 μm in the 90 minutes treatment case. Moreover, petrophysical measurements show that porosity increases from 8 to 19% at an optimal liquid nitrogen (LN 2 ) treatment duration (90 minutes). Furthermore, the permeability of the samples increased from 31 to 53 md after treatment with liquid nitrogen. Results from nanoindentation studies after LN 2 treatment revealed a significant decrease in nanoindentation moduli because of the increase in cracked rock compressibility.

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“…EOR methods can be classified into three major classes: chemical, gas injection, and thermal methods. Depending on the EOR method used, they can enhance the oil recovery once introduced to a reservoir by reducing the oil viscosity, and altering viscous forces and the bond between oil-water-rock facilitating the mobility of the residual oil [ 6 , 7 ].…”

Section: Introductionmentioning

confidence: 99%

Synthesis, Characterization, and Assessment of a CeO2@Nanoclay Nanocomposite for Enhanced Oil Recovery

et al. 2020

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In this paper, synthesis and characterization of a novel CeO2/nanoclay nanocomposite (NC) and its effects on IFT reduction and wettability alteration is reported in the literature for the first time. The NC was characterized using scanning electron microscopy (SEM), X-ray diffraction (XRD), Fourier-transform infrared spectroscopy (FTIR), thermogravimetric analysis (TGA), energy-dispersive X-ray spectroscopy (EDS), and EDS MAP. The surface morphology, crystalline phases, and functional groups of the novel NC were investigated. Nanofluids with different concentrations of 100, 250, 500, 1000, 1500, and 2000 ppm were prepared and used as dispersants in porous media. The stability, pH, conductivity, IFT, and wettability alternation characteristics of the prepared nanofluids were examined to find out the optimum concentration for the selected carbonate and sandstone reservoir rocks. Conductivity and zeta potential measurements showed that a nanofluid with concentration of 500 ppm can reduce the IFT from 35 mN/m to 17 mN/m (48.5% reduction) and alter the contact angle of the tested carbonate and sandstone reservoir rock samples from 139° to 53° (38% improvement in wettability alteration) and 123° to 90° (27% improvement in wettability alteration), respectively. A cubic fluorite structure was identified for CeO2 using the standard XRD data. FESEM revealed that the surface morphology of the NC has a layer sheet morphology of CeO2/SiO2 nanocomposite and the particle sizes are approximately 20 to 26 nm. TGA analysis results shows that the novel NC has a high stability at 90 °C which is a typical upper bound temperature in petroleum reservoirs. Zeta potential peaks at concentration of 500 ppm which is a sign of stabilty of the nanofluid. The results of this study can be used in design of optimum yet effective EOR schemes for both carbobate and sandstone petroleum reservoirs.

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Productivity index enhancement by wettability alteration in two-phase compressible flows

Cited by 30 publications

References 35 publications

Analytical Exact Solution for Co-Current Spontaneous Imbibition in Porous Media Considering Early- and Late-Time Effects

Analytical Exact Solution for Co-Current Spontaneous Imbibition in Porous Media Considering Early- and Late-Time Effects

Effect of Cryogenic Liquid Nitrogen on the Morphological and Petrophysical Characteristics of Tight Gas Sandstone Rocks from Kirthar Fold Belt, Indus Basin, Pakistan

Synthesis, Characterization, and Assessment of a CeO2@Nanoclay Nanocomposite for Enhanced Oil Recovery

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