The middle to deep coalbed methane reservoirs have the characteristics of higher burial depth, developed natural fractures and cleats, and are susceptible to damage from gel residue. To solve those problems, a CBM thickener was synthesized by using 2-acrylamido-2-methylpropanesulfonic acid (AMPS), acrylic acid (AA), methacryl propyl trimethyl ammonium chloride (DMC), and hydroxyethyl methacrylate (HEMA) monomers as raw materials through aqueous solution polymerization. The molecular structure and aqueous solution morphology were characterized by Fourier transform infrared spectroscopy (FTIR), nuclear magnetic resonance hydrogen spectroscopy (1H NMR), and scanning electron microscopy (SEM), respectively. The drag reduction rate and viscosity of different thickener dosages were tested. When the thickener dosage were 0.1 wt%∼1.0 wt%, the drag reduction rate were 81.3%∼61.5%, and the viscosity was 6 mPa·s∼117 mPa·s, and further exploration was conducted by using a rheometer to investigate the temperature and shear resistance at 25–120 °C and the viscoelasticity at 25 °C and 120 °C of 0.6 wt% thickener aqueous solution, indicating its good performance as a fracturing fluid. Finally, the gas permeability changes of the gel breaker with a thickener dosages of 0.4 wt%∼1.0 wt% were investigated to calculate its matrix damage rate, which corresponds to 9.2%∼11.1%, and SEM have been used to characterize the morphological changes of the rock core before and after the gel breaker solution displacement, and verify its damage mechanism. Ultimately, it was proven that the synthesized CBM thickener can be suitable for fracturing operations in middle to deep coalbed methane, with high efficiency in drag reduction and low matrix damage rate.
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