Laboratory Experimental Study on Polymer Flooding in High-Temperature and High-Salinity Heavy Oil Reservoir

Abstract

Polyacrylamide (HPAM) and other traditional polymers have poor temperature resistance and salinity tolerance and do not meet the needs of high-temperature and high-salinity reservoirs. In this study, a new temperature-resistant and salinity-tolerant polymer QJ75-39 was synthesized using acrylamide (AM) as a hydrophilic monomer, 1-acrylamide-2-methylpropanesulfonic acid (AMPS) and N-vinylpyrrolidone (NVP) as functional monomers and DS-16 as a hydrophobic monomer. Through laboratory experiments, the properties (temperature resistance, salinity tolerance and aging stability), polymer injection and core displacement effect of the polymer were studied. The experimental results showed that the new polymer could meet the needs of polymer flooding technology in high-temperature and high-salinity reservoirs. Experiments showed that the polymer had a temperature resistance of 95 °C and a salinity tolerance of 1.66 × 105 mg/L. When the temperature was 95 °C and the TDS was 55,376.8 mg/L, the viscosity of the polymer was 31.3 mPa s, and the viscosity remained above 30 mPa·s after aging for 60 days. The polymer had good injectivity between 300 and 600 mD, and the injection pressure could reach equilibrium quickly. The oil recovery effectively increased with the grsowth in the amount of injected polymer. When the injection amount was 0.5 PV, the enhanced oil recovery was 20.65%. This study is of great significance for the application and popularization of polymer flooding technology in high-temperature and high-salinity reservoirs.

Study of a novel cross linked graft copolymer starch in water-based drilling fluid

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Experimental Insights to Stability of Graphene Oxide Polymer Hybrid: Effect of Salinity, Temperature and Divalent Ions Coupled with ANOVA Statistical Analysis

“…This bond leads to the deformation and coiling of polymer molecules and, accordingly, a signi cant reduction in viscosity and may even result in polymer precipitation (Chauveteau and Zaitoun, 1981). In addition to salinity and hardness, temperature is also a crucial factor affecting the performance of polymer ooding (Zhang et al, 2022). An increase in temperature accelerates the speed of polymer hydrolysis and, consequently, reduces viscosity and possible sedimentation (Rashidi et al, 2011).…”

An Experimental Study and Numerical Simulation Analysis of Thermal Oxidation Characteristics Based on Kinetic Parameters in Heavy Oil Reservoirs

“…These factors make economically efficient production extremely challenging [7]. After years of water injection development practice, it has been observed that due to the high viscosity of crude oil, significant differences in oil-water mobility, and severe reservoir heterogeneity, it is prone to forming preferential water flow channels, leading to limited water flooding effectiveness [8,9]. Through the implementation of heavy oil cold production technologies such as foam flooding, chemical viscosity reduction, and gas injection cycles, the water flooding recovery rate has improved.…”