Pipeline projects involve high loads and flammable materials, making the integrity of girth welds critical. This RP ensures that different AUT systems are qualified on a "common and fair basis," accounting for project-specific variables like weld bevel configuration and material type.

In the lateral direction, F118 uses a passive earth pressure model, but modifies it for pipe geometry. The peak lateral resistance is:

That’s where plays a key role.

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Formally titled "Pipeline Cracking Management," this Recommended Practice (RP) provides a holistic framework for managing cracking in steel pipelines used for hydrocarbon and CO₂ transport.

The DNV-RP-F118 guideline reflects best practices and industry trends in geotechnical engineering, including:

In the world of subsea and onshore pipeline engineering, few factors are as unpredictable—or as critical—as the soil that surrounds the pipe. For decades, the oil and gas industry relied heavily on DNV-RP-F109, a standard focused on subsea pipeline soil interaction. However, as pipelines push further into challenging onshore terrains, arctic permafrost zones, and high-risk landfall locations (the transition point between offshore and onshore), engineers realized that a different set of rules was required.

Modern qualification processes increasingly incorporate . Tools like CIVA allow engineers to predict how ultrasonic waves will interact with specific weld geometries before physical testing begins. DNV-RP-F118 recognizes the value of these simulations in optimizing the qualification process and reducing the high cost of physical test welds. Why It Matters

Before F118, engineers often misapplied subsea standards to onshore projects. Subsea pipelines are subject to hydrodynamic loads and often rest on the seabed. Onshore pipelines, by contrast, are typically buried. The soil resistance is significantly higher, and the thermal cycles are different.

Executing rigorous test programs on welds containing known, seeded defects. This often includes: