Aging floating production, storage, and offloading (FPSO) vessels operating far offshore present a stubborn paradox: the assets most in need of continuous integrity data are often the hardest places to collect it. In a recent Emerson webinar, Digitalizing FPSO Asset Integrity in Africa: From Reactive to Proactive, corrosion and upstream specialists George Varughese, Vinicius Tirolla, Vinu Thomas, and Sameer Ahmad walked through how wireless, non-intrusive sensor technologies and modern software platforms are helping resolve that tension without requiring a single process shutdown.

Why It Matters

Many floating production vessels now operating off Africa and elsewhere were converted or built decades ago and are approaching or exceeding their original design lives. The monitoring equipment installed during that era is equally dated, leaving integrity teams dependent on manual ultrasonic inspections, retrievable corrosion coupons, and intrusive probes. Those methods demand personnel on board, hot-work permits, scaffolding, and sometimes partial or full shutdowns to be executed safely. The result is intermittent data collected at irregular intervals, stored in disconnected silos, and difficult to correlate with live production parameters. For assets where unplanned downtime carries enormous financial and safety consequences, that data gap is a growing liability.

Key Takeaways

• Non-intrusive, wireless sensors can be retrofitted onto live systems in minutes, eliminating drilling, welding, pressure testing, or process interruption. A single ultrasonic thickness sensor can be deployed in roughly five minutes.
• Continuous corrosion and erosion data replaces snapshot inspections, enabling real-time trend analysis, predictive maintenance, and immediate detection of upset conditions before metal loss occurs.
• Combining acoustic sand detection with thickness monitoring creates a powerful integrity and production optimization toolset, letting operators push well performance higher while keeping asset risk within acceptable bounds.
• The same wireless infrastructure scales beyond integrity monitoring to support temperature, pressure, valve, heat-exchanger, and safety-valve monitoring, making the initial deployment a gateway to broader digital transformation.

Corrosion Monitoring

The Rosemount non-intrusive wireless corrosion sensors at the center of the discussion are electromagnetic transducer-based ultrasonic devices that mount externally on pipe surfaces. They require no coupling, no cabling, and no surface preparation beyond selecting the monitoring location based on existing risk-based inspection programs or previous manual inspection data. Each sensor is battery-operated, zone-classified for hazardous areas, and transmits a thickness reading every 12 hours under default settings, yielding approximately nine years of battery life. Reading frequency can be adjusted remotely for shorter-term campaigns such as inhibitor performance testing.

Communication relies on the WirelessHART protocol operating in a self-organizing mesh network. Rather than each sensor needing a direct line of sight to a controller, devices relay data through one another. If a physical obstruction disrupts one path, the mesh reconfigures automatically with no manual intervention. Data flows to a gateway and onward to a server hosting Emerson’s Plantweb Insight software, which automates rate calculations, predictive analysis, and early-warning alerts for onset of corrosion events before actual metal loss occurs. That data can then be backhauled onshore through whatever connectivity the vessel already supports, whether subsea fiber, satellite link, or commercial broadband services.

Vinicius illustrated the value with a deepwater case from Brazil. An operator running high-pressure gas injection lines on floating production vessels faced a persistent problem: retrieving corrosion coupons and probes required reducing line pressure or shutting down the process entirely, exposing personnel to hydrocarbon hazards each time.

The solution was to place four externally mounted sensors around a gas injection pipe. The sensor at the six o’clock position tracked the corrosion effect of free liquid pooling at the bottom, while the remaining three captured condensation-driven corrosion across the pipe circumference. The pilot proved that the technology could meet the country’s regulatory monitoring requirements without intrusive access, and the operator subsequently rolled out the approach across its entire fleet.

A second use case demonstrated how the same sensors optimize chemical treatment programs. By positioning multiple devices downstream of an inhibitor injection point on a flow line, an operator could validate the chemical’s spread along the pipe and determine whether the dosage could be safely reduced. Even a fractional reduction in chemical consumption, on the order of half a percent to one percent, was sufficient to cover the return on investment for the entire monitoring deployment, while giving the integrity team continuous confirmation that the mitigation strategy was working.

A third case involved an operator managing a fleet of four aging platforms. The company replaced all critical coupon and probe locations with non-intrusive sensors across water injection, gas injection, flow lines, export lines, dew point plants, dehydration plants, and sweetening plants. The primary gain was a sharp reduction in personnel-on-board requirements.

Instead of scheduling crew rotations, permits, and scaffolding simply to retrieve coupons, integrity engineers could monitor every critical point from an onshore desk. The business case that justified the corrosion deployment also enabled the same team to add pressure safety valve monitoring, detecting whether valves were opening and closing correctly or leaking, all on the same wireless infrastructure.

Sand Management

For operators in regions where sand production is a persistent concern, the presenters highlighted the ROXAR acoustic sand monitor, which clamps externally to the pipe without process intrusion. It delivers three distinct outputs: a real-time sand alarm for zero-tolerance operations, a calculated sand rate for facilities that accept controlled sand ingress, and an accumulated sand total that supports maintenance planning for pipeline scraping and separator cleaning. The same sensor, with a minor design and software adjustment, can also function as a pig signaler during pipeline scraping operations, providing instantaneous confirmation of pig movement at any location along the line.

The most compelling deployment pairs acoustic sand detection with ultrasonic thickness sensors on the same flow line. This combination, proven in the North Sea, Latin America, and the United States, gives operators a unified view of how much sand is entering the system and whether it is actually eroding the pipe wall. George underscored the difference in risk timelines: corrosion degrades assets over months or years, but uncontrolled sand can damage a critical component in minutes.

With both data streams visible simultaneously, operators can push well performance closer to optimal production rates while keeping erosion risk visible and bounded. The presenters described this paired approach as a sand management suite that serves both asset integrity and operations teams.

Scalability

George emphasized that asset integrity monitoring should not be viewed in isolation. The wireless mesh network and software platform that support corrosion and sand sensors also accommodate more than 60 other device types within Emerson’s portfolio, including pressure, temperature, valve position, heat-exchanger performance, and compressor monitoring.

The Brazil case demonstrated this directly: once the corrosion pilot proved the wireless infrastructure, instrumentation, and operations teams began deploying temperature sensors on compressors to prevent line icing, and added monitoring to secondary heat exchangers that had never been instrumented because they were not considered critical enough to justify cabling.

The software layer scales in parallel. Plantweb Insight operates on a modular, app-like architecture. An organization can begin with the corrosion monitoring module and later activate additional applications for pump health, steam trap performance, heat-exchanger efficiency, or other asset classes without replacing the underlying platform. The software supports unlimited users, can manage multiple vessels or upstream assets from a single deployment, and segments access by location and responsibility.

The presenters also made the forward-looking point that continuous, location-specific data collected today becomes the training foundation for digital twin and artificial intelligence models tomorrow. Every asset has a unique integrity signature; models built on borrowed data from other facilities will always be less reliable than those grounded in measurements from the asset itself. By deploying even a limited set of wireless sensors now, organizations are not only solving today’s monitoring gaps but building the data foundation their future platforms will require.

To explore how continuous, non-intrusive monitoring and predictive analytics can strengthen integrity programs across your upstream assets, visit the Asset Performance Management section on Emerson.com.