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Abstract

Summary

Deposition of inorganic salt can cause formation damage and reduction of oil production from the reservoirs. This process occurs more during waterflooding. Different parameters affect the permeability reduction due to salt precipitation. In this work, to investigate formation damage, coreflooding experiment was conducted. For this purpose, two injection and formation waters were injected into the real core samples. The rock permeability, before and after salt precipitation, was determined under reservoir conditions. The tests were performed at different reservoir temperatures (60, 80, 100 °C). The results showed that the increasing temperature caused more formation damage. After completing the experiment, the damaged permeability reached to 55 % of initial permeability of core samples. Based on the data obtained from experimental work, a new correlation was developed for prediction of formation damage due to salt precipitation using the Matlab program. The predicted values using the correlation are near the experimental data. It confirms that the correlation can be used to predict formation damage with high accuracy. The correlation depends on the temperature, injection rate, ion concentration, and pore volume injected.

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/content/papers/10.3997/2214-4609.201700084
2017-03-27
2024-04-23

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References

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http://instance.metastore.ingenta.com/content/papers/10.3997/2214-4609.201700084
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Investigation of Formation Damage of Reservoir Rocks Due to Inorganic Salt Precipitation
Conference Proceedings 2017, 1 (2017); https://doi.org/10.3997/2214-4609.201700084
/content/papers/10.3997/2214-4609.201700084
/content/papers/10.3997/2214-4609.201700084
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