The production of very high TDS produced waters and how to treat them for reuse is one of the major problems associated with shale gas and oil production. As the flowback water is produced in the first few days, the TDS typically increases to some peak value (often 100 to 200 k-mg/L TDS) and then levels off as the flowback water ends and the lower rate of produced water commences. These flowback and produced waters are challenging to the operator. It would be desirable to reuse 100% of these waters, but the presence of frac additives, friction reducers, the higher TDS, and specific composition often prevents the water from being reused. In addition, there are significant challenges related to the produced water composition, mineral scale formation, hydrogen sulfide, microbial contamination, and corrosion, to mention a few. Testing and modeling of these complex produced water systems has been a focus of our research with emphasis on modeling the unusually high TDS/compositions and special requirements of strictly anoxic (&lt;&lt; 1 ppb O<sub>2</sub>) scale and corrosion testing regimes. It has been found that most models of solution chemistry at high temperature, pressure and compositions are inadequate and new measurements and modeling results have been developed that better match field conditions. Finally, results will be presented that support the importance of strictly anoxic testing for scale and corrosion inhibitor evaluation.

Shale gas and oil flowback and produced water modeling and treatment

249th National Meeting (2015)

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