Aqueous Formulations of Associating Polymers: Thermothinning versus Thermothickening.

Hourdet, Dominique; Badiger, Manohar V.; Gadgil, Jayant; Iyer, N. Padmanabha; Perrin, Patrick; Wadgaonkar, Prakash P.

doi:10.1063/1.2964757

Cited by 1 publication

(1 citation statement)

References 5 publications

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“…In contrast, for the TVP polymer, high temperature becomes a favorable factor to enhance its viscosity buildup ability, which makes it possible to achieve oil and gas production in high-temperature reservoirs. Moreover, some studies (L'Alloret et al 1995;Hourdet et al 1998Hourdet et al , 2005Hourdet et al , 2008 also found the addition of salts could further enhance the hydrophobic interaction between those thermoresponsive grafts, contributing to the strengthening thermoviscosifying ability. The temperature and salt-induced thickening capability of TVPs could offer a fluid for oil and gas production in high-salinity and hightemperature reservoirs.…”

Section: Introductionmentioning

confidence: 99%

A salt-induced viscosifying smart polymer for fracturing inter-salt shale oil reservoirs

Yin

Zhang

et al. 2019

Pet. Sci.

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Inter-salt shale oil reservoirs located between two salt layers are always accompanied by high temperature and high salinity. However, the present commonly used water-soluble polymers in fracturing fluids suffer from poor tolerance to high temperature and high salinity. Thermoviscosifying polymers (TVP) whose aqueous solution shows viscosity increase upon increasing temperature and salt concentration have received considerable attention recently, which is promising for utilization in fracturing fluids to overcome these problems. In this work, both the salt-induced viscosifying property and mechanism of a TVP solution were investigated and the performance of TVP used as fracturing fluid based on the conditions of the Jianghan inter-salt shale oil reservoir in China was evaluated. It is found that the salt-induced viscosifying property of the TVP solution decreases with temperature and shear rate, but increases with polymer concentration. The number of intermolecular hydrophobic domains increases with the salt concentration contributing to the strengthening of a 3D network structure, which results in an increase in viscosity. In addition, the TVP fracturing fluid formulated with saturated brine exhibits excellent temperature and shear resistance, sand-suspending performance, and gel-breaking performance. Its viscosity remains above 50 mPa s after being sheared for 1 h even at a high temperature of 140 °C and the sand-suspending stability can be maintained for more than 1 week at 100 °C. Furthermore, the fracturing fluid can be easily broken down within 12 h using 0.2 wt%-0.3 wt% potassium persulfate without residue.

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Section: Introductionmentioning

confidence: 99%