A High Temperature and Salt Resistance Supramolecular Thickening System
- Yingxian Ma (Southwest Petroleum University) | Leyao Ma (Southwest Petroleum University) | Jianchun Guo (Southwest Petroleum University) | Jie Lai (Southwest Petroleum University) | Han Zhou (Downhole Service Company, CNPC Chuanqing Drilling Engineering Company Limited) | Jia Li (Downhole Service Company, CNPC Chuanqing Drilling Engineering Company Limited)
- Document ID
- Society of Petroleum Engineers
- SPE International Conference on Oilfield Chemistry, 8-9 April, Galveston, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Thickening System, Fracturing fluid, High temperature resistance, Double network structure, Salt tolerance
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- 93 since 2007
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We prepared physically linked allyl alcohol polymer/polyacrylamide double network hydrogels via one-pot strategy. These double network supermolecular fracturing fluids were found to have a better viscosity at high temperature compared to the conventional polyacrylamide systems. After testing with a rheometer, the fluid viscosity could stay 320 mPa s at 150 °C under 170/s shear rate. With NMR and FT-IR results' help, we determined that abundant polar groups of chains were still free, which could complex ions to keep, even enhance the chain stability. Thus, these double network systems showed excellent salt resistance with the non-covalent interactions and physical entanglements, and the viscosity of the allyl alcohol polymer/polyacrylamide system did not drop but increase. The viscosity in high salinity could increase nearly 40 % compared with the initial situation. Overall, the novel fracturing fluid system could maintain a high viscosity and better rheological properties under high salinity and showed excellent high-temperature stability, to make up the lack of fracturing fluid at this stage. It is expected to potential fluid issues caused by low water quality and harsh downhole temperatures were resolved or mitigated.
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