Experimental Study on the Effect of the Water-Cut Conditions on the Performance of L80 Carbon Steel
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TECHNICAL ARTICLE—PEER-REVIEWED
Experimental Study on the Effect of the Water-Cut Conditions on the Performance of L80 Carbon Steel K. Al-Muhanna • K. Habib
Submitted: 13 June 2012 / in revised form: 22 November 2012 / Published online: 11 December 2012 Ó ASM International 2012
Abstract In the oil production, water and acidic gases, i.e., H2S and CO2, are co-produced with the oil. The acidic gases are known to associate with a variety of corrosion damage to the surface facilities leading to costly failures. Also, the acidic gases cause a reduction in the service life of equipment. Corrosion of API L80 tubular carbon steel in sweet media (in the presence of CO2 gas) was investigated using the linear polarization resistance meter. Experiments using API L80 tubular carbon steel material were carried out in a stagnant flow condition with different ratios of produced water to crude oil at relatively high temperatures (60 °C up to 90 °C). The pressure was about 200 psi (13.8 bar) of CO2, and the experiments were carried out using a high pressure vessel namely an autoclave cell. Under those experimental conditions, results indicated that at a temperature of 60 °C, the corrosion rate for carbon steel L80 increased as water-cut ratio increased. Also, the results showed that at higher temperature than 60 °C, the formation of iron carbonate scale on the surface of the steel was observed to increase. Consequently, the corrosion rate of the L80 carbon steel was observed to decrease. Keywords Downhole corrosion Water-cut Corrosion rate break Sweet corrosion Carbon steel LPR meter
K. Al-Muhanna K. Habib (&) Materials Science Laboratory, Department of Advanced Systems, Kuwait Institute for Scientific Research (KISR), P.O. Box 24885, Safat 13109, Kuwait e-mail: [email protected]
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Introduction The petroleum industry contains a wide variety of corrosive environments such as H2S and CO2 gases. The dissolved acid gases (H2S and CO2) in water cause severe corrosion of steels. Corrosion of steels in acid gases of H2S and CO2 environments is known as sour corrosion and sweet corrosion, respectively. In addition to their effect on both capital and operational expenditures, sweet corrosion and sour corrosion have negative influence on health, safety, and the environment. It has been reported that 25% of safety incidents, 2.8% turnover, 2.2% tangible asset, 8.5% increase on capital expenditure, 5% of lost/deferred production, and 11.5% increase to the lifting costs are referred to the CO2 corrosion in the oil production [1]. CO2 systems are one of the most common environments in the oil field industry where corrosion occurs. Corrosion rates in a CO2 system can reach very high levels, but it can be effectively inhibited. It is well known that the velocity effects are very important in the CO2 system; turbulence is often a critical factor in pushing a sweet system into a corrosive regime. Areas where CO2 corrosion is most common include flowing wells, gas condensate wells, areas where water condenses, tanks filled with CO2
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