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A life cycle cost assessment led to the selection of DSS for field gas gathering network composing of more than 200 miles of pipelines. Buried portions are provided with external coating. Furthermore, due to high chloride content in the soils, the external corrosion threat was mitigated through the use of an external coating supplemented with CP.
As there was no industrial reference covering onshore DSS pipeline CP criteria, lab testing was conducted to establish the criteria and confirm if the risk of hydrogen embrittlement is managed appropriately. This is further evaluated with field data to confirm pipelines integrity.
Duplex stainless steel (DSS) is selected for wet gas pipeline to minimize OPEX and eliminate maintenance activities for internal corrosion control. DSS, however, requires a combination of coating and cathodic protection (CP) for external corrosion mitigation due to harsh external conditions (e.g., high operating temperature and high chloride level in the soil) in the Middle East. CP design and operation for DSS pipeline faces a major challenge as there is no applicable published industry standard or technical research for protection criteria for DSS.
During the last decades, low alloyed steels with improved resistance to Sulfide Stress Cracking (SSC) have been developed for covering specific applications as heavy wall casings1 or expandable tubings2 or for reaching higher mechanical properties, such as 125 ksi Specified Minimum Yield Strength (SMYS) materials.3-6 For the latter, relevant sour environments for developed grades are mild, meaning that all sour applications cannot be covered while a strong interest exists for O&G operators to use high strength materials when designing wells. Consequently, there is an incentive to push the limits of use of high strength sour service steels by enhancing their resistance to SSC. Several recommendations were already published when designing high strength sour service grades: hardness level shall be limited as much as possible and be preferentially below 22 HRC7, microstructure shall present a minimum required amount of martensite8 which is well known to be ideal for combining high mechanical properties and high resistance to hydrogen. Besides, many authors highlighted some other influencing parameters related to the material or the process.
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Corrosion control of buried assets usually involves a double shield: a coating system as a physical insulation barrier, and a cathodic protection system as an additional ad hoc defense. Detection of a corrosion spot at the coating defect stage is the only way to identify the threat before significant metal loss occurs. Furthermore, detection of defects in the coatings of such assets is especially important, since large defects, if left unrepaired, will not only leave the asset locally prone to corrosion, but also drain and weaken the cathodic protection effectiveness for the entire structure. Therefore, identification and characterization of coating anomalies is critical for the integrity of buried assets.