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Abstract

Summary

Since the first single well associative polymer injection test in offshore reservoir in Bohai in 2003, ,24 injectors corresponding to 105 producers were reported as of 2019 in Bohai offshore reservoir. Incremental oil recovery factor (IORF) was 7.1% original oil in place (OOIP) and the polymer utility factor was 45 ton oil/ ton polymer powder. However, associative polymer was not widely used in many other oilfields like Daqing and Shengli in China. This raised the question that whether associative polymer is a better or not choice for polymer flooding. Thus, a critical review of polymer flooding in offshore reservoir in the past 17 years was to be presented based on many public references published. Different from previous publication which focused on positive aspects of polymer flooding achievements, both success and lessons were given to help understand the benefit and challenges of using polymers in offshore reservoirs. The plugging was reported in many wells. The produced fluid was more difficult to treat with than that from common polymer. The IORF was lower compared to laboratory core flooding tests and other similar reservoirs like Shengli. It is interesting that although water cut decrease of 41% in one producer was reported, the significantly water cut decrease in the region was not as obvious as many other onshore reservoirs. Problems and progress in produced water treatment and reinjection, oil-water separation and plugging mechanism study were discussed. Surface-active polymer largely increased the difficulty of produced water treatment, and presence of Fe2+and S2- made the emulsion more stable. Emulsification oil in produced fluids accounted for 90%, which added difficulty. Large amount of cationic chemicals are required to break the stable interface of oil-in-water emulsion. During the flocculation and sedimentation process, the oil droplets and other suspended solids are gathered, resulting in the formation of a large number of colloidal solid products, which provided plugging. The blockages in the production wells are mainly inorganic scales. The inorganic scales in the benefited oil wells and polymer injection wells are mainly Fe2O3 and CaCO3, respectively. The organic scales are partially hydrolyzed polyacrylamide and coordinate with Fe3+ under acidic conditions, resulting in insoluble water cross-linked polymer micelles. Current acid dissolution method and oxidative degradation method used in Bohai offshore increased the risk of well damage. Associative polymer partly caused the plugging which becomes a more and more difficulty issue.

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2021-04-19
2024-04-25

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Lessons Learned from Offshore Polymer Flooding Practices
Conference Proceedings 2021, 1 (2021); https://doi.org/10.3997/2214-4609.202133021
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