Speaker
Description
Low salinity water (LSW), carbonated water (CW), micellar solutions, acids are some of the smart fluids injected into the reservoir to optimize recovery. Though, these fluids help to improve the oil recovery, they also have a detrimental effect on the integrity of the oil and gas production facility due to material degradation resulting from corrosion. The aim of this study is to develop a screening tool to assess the corrosion tendency of injected fluid under both surface and reservoir conditions. Both experiment and simulation techniques were used. The properties of the materials as employed in the experiment were used as input into the geochemical model. The metal samples considered in this study were high carbon steel (HCS), low carbon steel (LCS) and stainless steel (SS) while the injection fluid employed are distilled water (DW), brine and acidic-brine.
To add to the above, HCS and LCS resulted in the highest corrosion rate (i.e. 3.176 mm/year and 3.135 mm/year, respectively) while the SS demonstrated relatively low corrosion rate (i.e. approximately 0.237 mm/year) in the acidic-brine environment. This was attributed to the protective layer from its chromium (Cr) content. The corrosion rate of the galvanized nail was also negligible (0.0305 –0.0512 mm/year) due to the sacrificial protection from the zinc.
A novel technique of screening the corrosion tendencies of oil and gas production facilities has been developed. This is a fast technique of predicting the corrosion tendencies of both surface and downhole equipment using their material properties.
| Final Abstract | f1 |
|---|