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03121 AN ENGINEERED APPROACH TO CORROSION CONTROL DURING MATRIX AClDIZING OF HTHP SOUR CARBONATE RESERVOIR

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Product Number: 51300-03121-SG
ISBN: 03121 2003 CP
Author: Donald G. Hill, Alison Jones
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Conventionally, matrix acidizing treatments have not been performed in HPHT wells with temperatures much above 150°C, because of the limitations on acid retardation technologies of hydrochloric acid (HCI) and the inhibition of corrosion of these fluids at elevated temperatures. This paper presents the corrosion studies for the design of an acid treatment performed on a gas well in a naturally- fractured, tight carbonate under conditions that were beyond the limit of conventional matrix acidizing experience. Stimulation of the well required acid to be placed below fracturing pressures into the natural fracture system beyond the near wellbore region. The reservoir was deep (16,000 ft \[5,000 m\]), sour (2 to 4% H2S) and at high temperature (~170°C) and pressure (>8,700 psi \[600 bar\]). Ensuring success of such an operation requires detailed design, involving extensive laboratory testing of fluid properties, corrosion evaluation and design of placement techniques. The factors that need to be considered for such treatments, namely balancing the conflicting requirements of acid reaction and corrosion, acid stability and placement, are illustrated using details from the case study. A critical issue was designing a fluid system and a placement method that achieved the required penetration and placement over the target interval while maintaining acceptable corrosion inhibition.

Keywords: Acid Stimulation, Acid Corrosion, Corrosion Inhibition, and Corrosion Test Procedures
Conventionally, matrix acidizing treatments have not been performed in HPHT wells with temperatures much above 150°C, because of the limitations on acid retardation technologies of hydrochloric acid (HCI) and the inhibition of corrosion of these fluids at elevated temperatures. This paper presents the corrosion studies for the design of an acid treatment performed on a gas well in a naturally- fractured, tight carbonate under conditions that were beyond the limit of conventional matrix acidizing experience. Stimulation of the well required acid to be placed below fracturing pressures into the natural fracture system beyond the near wellbore region. The reservoir was deep (16,000 ft \[5,000 m\]), sour (2 to 4% H2S) and at high temperature (~170°C) and pressure (>8,700 psi \[600 bar\]). Ensuring success of such an operation requires detailed design, involving extensive laboratory testing of fluid properties, corrosion evaluation and design of placement techniques. The factors that need to be considered for such treatments, namely balancing the conflicting requirements of acid reaction and corrosion, acid stability and placement, are illustrated using details from the case study. A critical issue was designing a fluid system and a placement method that achieved the required penetration and placement over the target interval while maintaining acceptable corrosion inhibition.

Keywords: Acid Stimulation, Acid Corrosion, Corrosion Inhibition, and Corrosion Test Procedures
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