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Since the most common use of matrix acidizing is the removal of formation damage, it is important to understand the nature of the damage that exists so that an appropriate treatment can be designed. Well testing and well test analysis generate a skin factor and well completion efficiency. This is insufficient alone for formation damage diagnosis. Well performance analysis has provided a beneficial tool to identify the location and thickness of damage at flow points in the near wellbore area. Models of flow into perforations and gravel-packed tunnels provide a way to relate the location and severity of damage to the completion procedure that preceded it.
Hassan, M. Hafiidz (PETRONAS Carigali Sdn. Bhd.) | Rusman, Liyana (PETRONAS Carigali Sdn. Bhd.) | Chandrakant, Ashvin A. (PETRONAS Carigali Sdn. Bhd.) | Haslan, M. Hanif (PETRONAS Carigali Sdn. Bhd.) | Moktar, Nur Syazwani (PETRONAS Carigali Sdn. Bhd.) | Abdussalam, Khomeini (PETRONAS Carigali Sdn. Bhd.)
Abstract Matrix acidizing is an attractive treatment choice in clastic reservoirs to remove near-wellbore damage due to its relatively low cost. It has been executed countless times in brownfields East Malaysia with a moderate to high success rate to arrest production decline due to fines migration and scale deposition. Nonetheless, there is a critical need to look back on the choice of treatment chemicals and treatment approach in order to ensure optimum chemical volume, attractive production gain and higher success rate, especially in the current low oil price era. This paper will focus on the planning and successful execution of single-stage acid (SSA) combined with wax solvent stimulation treatments resulting in fourfold increase in net oil production post treatment in two wells in Field X offshore East Malaysia. Well A18 and C33 experienced production impairment due to formation damage fines and organic scale. Combination of both wax solvent and SSA in the same treatment was used to remove the damage. Application of SSA eliminates the need for hydrochloric acid (HCl) pre and post flush thus reduces treatment volume, simplifies treatment execution and consequently reduces overall treatment time. Additionally, the usage of retarders eliminates fast reaction of hydrofluoric acid (HF) thereby allowing for deeper HF penetration. This paper also discusses the rapid decline observed post treatment for Well A18 is mainly contributed by re-mobilization of fines due to higher flow rates and re-buildup of wax within tubing and near wellbore. Proactive measures such as pressure drawdown management are suggested to prevent reoccurrence in future stimulation treatments. In conclusion, this paper finds that the combination of wax solvent and SSA was successful in both removing the damage and optimizing treatment schedule. Correct identification of damage source coupled with good treatment design was able to quadruple production from well A18 and C33 in Field X. This paper presents an innovative approach and cost effective solution in successfully mitigating formation damage caused by a combination of fines migration and organic scale. This single-stage stimulation treatment saves time, treatment volume and reduces job complexity.