An experimental study of inaccessible pore volume on polymer flooding and its effect on oil recovery

Swadesi, Boni; Saktika, Erdico Prasidya; Sanmurjana, Mahruri; Siregar, Simon; Rini, Dyah

doi:10.1063/5.0006957

Cited by 2 publications

(2 citation statements)

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“…The nanopolymer sol exhibits higher mechanical entrapment and IPV than the HPAM solution (Table ) due to its tridimensional network conformation. Also, these parameters could be affected by the low permeability of the rock used in the experimental test …”

Section: Resultsmentioning

confidence: 99%

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Flow Behavior through Porous Media and Displacement Performance of a SILICA/PAM Nanohybrid: Experimental and Numerical Simulation Study

Corredor,

Espinosa,

Delgadillo

et al. 2024

ACS Omega

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Nanoparticles (NPs) have been proposed as additives to improve the rheological properties of polymer solutions and reduce mechanical degradation. This study presents the results of the retention experiment and the numerical simulation of the displacement efficiency of a SiO 2 /hydrolyzed polyacrylamide (HPAM) nanohybrid (CSNH-AC). The CSNH-AC was obtained from SiO 2 NPs (synthesized by the Stober method) chemically modified with HPAM chains. Attenuated total reflection−Fourier transform infrared spectroscopy, field emission gun−scanning electron microscopy, X-ray diffraction, and thermogravimetric analysis were used to characterize the nanohybrid. The injectivity and dynamic retention tests were performed at 56 °C in a sandstone core with a porosity of ∼26% and a permeability of 117 and 287 mD. A history matching of the dynamic retention test was performed to determine the maximum and residual adsorption, IPV, and residual resistance factor (RRF). A laboratory-scale model was used to evaluate the displacement efficiency of CSNH-AC and HPAM through numerical simulation. According to the results, the nanohybrid exhibits better rheological behavior than the HPAM solution at a lower concentration. The nanopolymer sol adsorption and IPV (29,7 μg/g rock , 14,5) are greater than those of the HPAM solution (9,2 μg/g rock , 10), which was attributed to the difference between the rock permeabilities used in the laboratory tests (HPAM: 287 mD and CSNH-AC: 117 mD). The RF of both samples gradually increases with the increase in shear rate, while the RRF slightly decreases and tends to balance. However, the nanopolymer sol exhibits greater RF and RRF values than that of the polymer solution due to the strong flow resistance of the nanohybrid (higher retention in the porous media). According to the field-scale simulation, the incremental oil production could be 295,505 and 174,465 barrels for the nanopolymer sol and the HPAM solution, respectively (compared to waterflooding). This will represent an incremental recovery factor of 11.3% for the nanopolymer sol and 6.7% for the HPAM solution.

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Section: Resultsmentioning

confidence: 99%

“…Also, these parameters could be affected by the low permeability of the rock used in the experimental test. 75 3.4. Mobility (RF) and Permeability (RRF) Reduction.…”

Section: Dynamic Adsorption and Ipvmentioning

confidence: 99%