The Casing Tradeoff: Upfront Cost vs. Frac Efficiency

What Is Your Casing Really Costing You?

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5.5-inch casing is often selected because it keeps upfront well costs lower, while moving to a larger diameter increases casing cost. But casing size also directly impacts pipe friction during the frac – influencing treating pressure, achievable rates, chemical usage, and stage efficiency. In this field comparison, the hydraulic benefits of 6-inch vertical casing translated to lower treating pressure, reduced FR loading, faster stage execution, and an estimated $20,000–$40,000 in savings per well.

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A comparison between 5.5-inch and 6-inch vertical casing shows how an early well design decision can carry directly into frac performance and completion economics.

Why Pipe Friction Matters During Execution

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As pipe friction increases, more energy is lost before it ever reaches the perforations.

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That loss must be compensated for – with higher pressure, more chemicals, and/or slower execution.

The challenge is that pipe friction isn’t directly measured in the field. It’s typically estimated, which makes it difficult to quantify how much pressure is actually being lost.

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Across this dataset, stages with 5.5-inch monobore casing consistently operated in a more constrained hydraulic environment. They ran closer to pressure limits, required higher chemical loading to maintain performance, and took longer to execute. These are all surface symptoms of the same underlying issue: higher pipe friction.

Measuring Pipe Friction in Real Time

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SAFA changes that.

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By measuring pipe friction in real time at the well, SAFA isolates how much of the treating pressure is being consumed by the wellbore versus delivered to the formation.

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That separation is what makes it possible to clearly see the impact of casing design on execution.

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