The corrosive activity of water produced from offshore oil fields of Vietsovpetro JV

UDK: 620.193.27
DOI: 10.24887/0028-2448-2019-1-54-56
Key words: reservoir water, internal corrosion, water cut, oilfield pipeline, corrosion inhibitor
Authors: V.V. Savelev (Research and Engineering Institute, Vietsovpetro JV, the Socialist Republic Vietnam, Vung Tau), I.N. Cherniadev (Research and Engineering Institute, Vietsovpetro JV, the Socialist Republic Vietnam, Vung Tau)

The article presents the results of the studies of corrosion activity of water produced from the White Tiger, White Rabbit and Dragon oilfields operated by Vietsovpetro JV. Produced water in Vietsovpetro is a mixture of formation water and treated seawater used for waterflooding. There are substantial differences in chemical composition and content of corrosive components in water between different oilfields and even within one oilfield. Maturing of the oilfields leads to an increase in water cuts and in aggressive components content in produced water.

Oil gathering pipelines and oil processing equipment are made of ASTM A106, API 5X carbon steels. In Vietsovpetro the pipes and equipment made of carbon steels have been used successfully for more than 25 years, but in recent years corrosion damage was noticed on the inner surfaces of the pipes the oil gathering and transportation system. It was found that the present rate of corrosion of carbon steel in the conditions at which the system of gathering and transportation of the gas-liquid products operates (45 °С, 0.1 MPa) is 0.22-0.31 mm per year. At elevated pressures and temperatures (120 °С, 10 MPa) the corrosion rates increase to 0.26-0.64 mm per year. Corrosion aggressiveness of produced water is caused primarily by carbon dioxide, water and solid particles. The results of inspection of pipelines wall thickness after corrosive impact prove the high aggressive activity of produced water. Electrochemical corrosion that causes local defects (blisters) on the inner surface of the oil pipelines, transporting produced fluids with high water content, is caused primarily by formation of a separate water phase in the pipes and by presence of aggressive components in water.

A field trial of corrosion inhibitor injection into the gathering and transportation system was performed to reduce the internal corrosion. It was found that in presence of corrosion inhibitor the rate of corrosion lowers from 0.31 to 0.052 mm per year.

References

1. Zav’yalov V.V., Problemy ekspluatatsionnoy nadezhnosti truboprovodov na pozdney stadia razrabotki mestorozhdeniy (Pipelines operating reliability problems in the late stages of field development), Moscow: Publ. of VNIIOENG, 2005, 332 p.

2. Gordeev P.V., Shemelin V.A., Shulyakova O.K., Gidrogeologiya (Hydrogeology), Moscow: Vysshaya shkola Publ., 1990, 471 p.

3. Bushkovskiy A.L., Ivanov A.N., Chan Van Vinh, Le Cong Thuy, Corrosion activity of wells production and efficiency of protection of Vietsovpetro JV oil & gas producing equipment (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 7, pp. 112–115.

The article presents the results of the studies of corrosion activity of water produced from the White Tiger, White Rabbit and Dragon oilfields operated by Vietsovpetro JV. Produced water in Vietsovpetro is a mixture of formation water and treated seawater used for waterflooding. There are substantial differences in chemical composition and content of corrosive components in water between different oilfields and even within one oilfield. Maturing of the oilfields leads to an increase in water cuts and in aggressive components content in produced water.

Oil gathering pipelines and oil processing equipment are made of ASTM A106, API 5X carbon steels. In Vietsovpetro the pipes and equipment made of carbon steels have been used successfully for more than 25 years, but in recent years corrosion damage was noticed on the inner surfaces of the pipes the oil gathering and transportation system. It was found that the present rate of corrosion of carbon steel in the conditions at which the system of gathering and transportation of the gas-liquid products operates (45 °С, 0.1 MPa) is 0.22-0.31 mm per year. At elevated pressures and temperatures (120 °С, 10 MPa) the corrosion rates increase to 0.26-0.64 mm per year. Corrosion aggressiveness of produced water is caused primarily by carbon dioxide, water and solid particles. The results of inspection of pipelines wall thickness after corrosive impact prove the high aggressive activity of produced water. Electrochemical corrosion that causes local defects (blisters) on the inner surface of the oil pipelines, transporting produced fluids with high water content, is caused primarily by formation of a separate water phase in the pipes and by presence of aggressive components in water.

A field trial of corrosion inhibitor injection into the gathering and transportation system was performed to reduce the internal corrosion. It was found that in presence of corrosion inhibitor the rate of corrosion lowers from 0.31 to 0.052 mm per year.

References

1. Zav’yalov V.V., Problemy ekspluatatsionnoy nadezhnosti truboprovodov na pozdney stadia razrabotki mestorozhdeniy (Pipelines operating reliability problems in the late stages of field development), Moscow: Publ. of VNIIOENG, 2005, 332 p.

2. Gordeev P.V., Shemelin V.A., Shulyakova O.K., Gidrogeologiya (Hydrogeology), Moscow: Vysshaya shkola Publ., 1990, 471 p.

3. Bushkovskiy A.L., Ivanov A.N., Chan Van Vinh, Le Cong Thuy, Corrosion activity of wells production and efficiency of protection of Vietsovpetro JV oil & gas producing equipment (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 7, pp. 112–115.



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