Influencing factors for effective establishment of residual resistance factor of polymer solution in porous media

Experimental study on reducing the viscosity of sewage containing PAM catalyzed by low temperature plasma synergistic AC/Mn + TiO2

With the wide application of polymer flooding technology in oil fields, wastewater containing PAM (polyacrylamide) is produced. Its high viscosity makes it difficult to degrade. In this paper, the low-temperature plasma produced by DBD (Dielectric Barrier Discharge) was studied to reduce the viscosity of wastewater containing PAM under the synergistic action of AC (Activated carbon)/Mn + TiO2 catalyst. The effects of different amount of AC/Mn + TiO2 catalyst, discharge voltage and initial concentration of solution on viscosity reduction were studied. The change of functional groups in wastewater containing PAM was detected by FTIR (Fourier transform infrared absorption spectrometer), and the mechanism of catalytic viscosity reduction was analysed. The AC/Mn + TiO2 catalysts were analysed by XPS (X-ray photoelectron spectroscopy), XRD (X-Ray Diffraction) and ESEM (Field emission electron microscopy). With the increase of discharge voltage, the effect of catalytic viscosity reduction is enhanced. After 10 min of discharge, the effect of catalytic viscosity reduction is significantly enhanced. The catalytic viscosity reduction is best when discharge voltage is 18 KV and discharge time is 30 min. The viscosity reduction of polyacrylamide solution by low-temperature plasma AC/Mn + TiO2 is significant. When the amount of AC/Mn + TiO2 catalyst added is 544 mg, the viscosity of polymer containing solution can be reduced from 1758 mPa·s to 11.9 mPa·s, and the shear rate can be changed from 0 1/sec to 30 1/sec after the discharge for 30 min. The functional groups in solution did not change significantly and the element composition of AC/Mn + TiO2 catalyst did not change before and after catalytic discharge.

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

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 SiO2/hydrolyzed polyacrylamide (HPAM) nanohybrid (CSNH-AC). The CSNH-AC was obtained from SiO2 NPs (synthesized by the Stöber 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/grock, 14,5) are greater than those of the HPAM solution (9,2 μg/grock, 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.

Mechanistic Insights into a Novel Controllable Phase-Transition Polymer for Enhanced Oil Recovery in Mature Waterflooding Reservoirs

Expanding swept volume technology via continuous-phase polymer solution and dispersed-phase particle gel is an important technique to increase oil production and control water production in mature waterflooding reservoirs. However, problems such as the low viscosity retention rate, deep migration, and weak mobility control of conventional polymers, and the contradiction between migration distance of particle gel and plugging strength, restrict the long-term effectiveness of oil displacement agents and the in-depth sweep efficiency expanding capability in reservoirs. Combined with the technical advantages of polymer and particle gel, a novel controllable phase-transition polymer was developed and systematically studied to gain mechanistic insights into enhanced oil recovery for mature waterflooding reservoirs. To reveal the phase-transition mechanism, the molecular structure, morphology, and rheological properties of the controllable phase-transition polymer were characterized before and after phase transition. The propagation behavior of the controllable phase-transition polymer in porous media was studied by conducting long core flow experiments. Two-dimensional micro visualization and parallel core flooding experiments were performed to investigate the EOR mechanism from porous media to pore level. Results show that the controllable phase-transition polymer could change phase from dispersed-phase particle gel to continuous-phase solution with the prolongation of ageing time. The controllable phase-transition polymer exhibited phase-transition behavior and good propagation capability in porous media. The results of micro visualization flooding experiments showed that the incremental oil recovery of the controllable phase-transition polymer was highest when a particle gel and polymer solution coexisted, followed by a pure continuous-phase polymer solution and pure dispersed-phase particle gel suspension. The recovery rate of the novel controllable phase-transition polymer was 27.2% after waterflooding, which was 8.9% higher than that of conventional polymer, providing a promising candidate for oilfield application.