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Abstract

Summary

Shale formations are one of the unconventional reservoirs, development and operation of which requires special technologies. Waterflooding can be used for improving recovery factor in the shale reservoirs under specific conditions. Inorganic salt precipitation can occur during water injection into shale reservoir depending on the pressure and temperature. Scale formation reduces rock permeability, and damages the production equipment. In this work, prediction of barium sulfate scale deposits was investigated at different reservoir pressures (0.1 to 70 MPa) and temperatures (40°C to 150°C). The scaling tendency of barium sulfate was increased by increasing pressure and decreasing temperature. However, temperature did not affect the amount of salt precipitation. In addition, scale inhibition was studied using five different scale inhibitors under static and dynamic conditions. One of them is a new scale inhibitor package. The experimental results showed that the new scale inhibitor had the highest inhibition performance (more than 90%). Temperature and mixing ratio had a negligible effect on the scaling inhibition efficiency. The minimum inhibitory concentration of the new inhibitor package was 25 mg/L. Also, the new inhibitor had an enhanced adsorption and desorption rate on the shale rocks.

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/content/papers/10.3997/2214-4609.201700203
2017-04-10
2024-09-11

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References

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/content/papers/10.3997/2214-4609.201700203
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Prediction and Inhibition of Barium Sulfate Scale Deposits in Oil Reservoirs
Conference Proceedings 2017, 1 (2017); https://doi.org/10.3997/2214-4609.201700203
/content/papers/10.3997/2214-4609.201700203
/content/papers/10.3997/2214-4609.201700203
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