Pipelines are vast and complex networks delivering fossil fuel from remote locations to gas processing facilities refineries petrochemical manufacturers and refined products all the way to end users. Pipeline operators rely on Pipeline Integrity Management (PIM) systems to conduct safe and reliable hydrocarbon transportation operations cope with local regulations maximize transportation capacity and identify integrity threats.Internal and external corrosion are leading causes of incidents in pipelines that can lead to spills explosions and increased downtime. ASME describe the threats above as time-dependent; however they are commonly assessed with methods such as in-line inspection direct assessment and hydrostatic pressure tests whose measurement interval can range from months to years providing isolated snapshots throughout the pipeline lifetime. Moreover executing these techniques requires extensive planning and execution pipelines ready to accommodate in-line inspection tools and in some instances stop hydrocarbon transportation activities.Coping with increased demand pushes operators to boost their pipeline’s utilization rate to serve their customers and communities safely and reliably. In consequence PIM systems will require more data to constantly monitor dynamic changes along the infrastructure (either high consequence areas or not) and leverage predictive analytics. Increasing remote corrosion monitoring locations along several pipeline segments provide continuous input to feed PIM systems with on-line data that is seamlessly integrated into the operator’s control systems and data historian minimizing human intervention.This paper will explore remote corrosion monitoring technologies and how increasing real-time insights to risk maintenance and performance can increase reliability and decrease downtime through predictive analytics.

The presence of high concentrations of acid gases (H2S and CO2) in combination with produced water and elemental sulfur will normally require that a corrosion resistant alloy (CRA) is selected as the material of construction for such oil & gas production facilities to ensure long-term pressure equipment integrity and reliability. This paper presents a 30+ year history of an asset with excellent mechanical integrity and reliability despite using carbon steel in the presence of wet gas containing 5% H2S 65% CO2 and elemental sulfur. This history includes a review of internal corrosion management data such as chemical qualification/injection history corrosion inhibitor residual analysis corrosion rate monitoring trends and continuous improvement efforts.Lessons learned are also provided to illustrate the evolutionary nature of the process that lead to the robust corrosion management program described herein. Key success factors such as robust corrosion control program design and field implementation continuous improvement through frequent review of monitoring data excellent leadership support and a multidisciplinary team approach are described.

Failure of water/wastewater mains can result in high visibility repairs customer inconvenience and replacement costs. Preventive measures such as condition assessment for early recognition of corrosion in aging infrastructures is crucial for agencies from resiliency safety and economic standpoints but is not regulated as in the oil & gas industry. Internally deployed tools/technology or external excavations for direct assessment techniques provide valuable insight on the existing condition of buried structures but at a significant cost in terms of shutdown and technology expenses in addition to safety concerns for manned entries into confined spaces. Because of the cost and safety implications large diameter cement mortar lined (CML) pipe extensive and recurring direct assessments are less common in the water and wastewater industries. Indirect assessment techniques particularly the over-the-line potential surveys for condition assessment of water/wastewater lines can be conducted to determine active external corrosion areas. Traditionally over-the-line potential surveys were applied to electrically continuous pipelines. Most water/wastewater pipeline designs utilize rubber gasket bell-and-spigot joints. Unless electrical continuity is intentionally designed for the pipeline such joints result in a pipeline with no electrical continuity. This paper presents multiple case studies where over-the-line potential surveys were successfully applied on electrically discontinuous water pipelines. The results of over-the-line surveys correlated well with direct assessment techniques. The paper presents the methodology and results of such assessments and findings for various pipe materials.