In the late 2010s, an operator pushed shale development to the extreme by drilling and fracking 23 horizontal wells on a single pad. The idea was bold. The outcome wasn’t.
When the initial production data rolled in, reality hit hard. The wells were spaced at roughly 230 feet apart, compared to the more typical 600+ feet in that area. The spacing proved too tight, and the wells were on track to fall short of forecasted EUR by as much as 45%.
This raised an industry-wide question: How big can a pad get before diminishing returns kick in?
The answer became clear very quickly: bigger isn’t always better. Cramming wells shoulder-to-shoulder without holistic planning can crush per-well performance and destroy value at the pad level.
Beyond Single-Well Thinking
For years, shale development decisions were made one well at a time. Drill the best spot. Frac it hard. Hit a strong initial rate. Then move over and repeat.
But shale reservoirs don’t work in isolation.
Wells on the same pad or section interact sometimes like a tightly coordinated team, and sometimes like a cage match. A narrow focus on maximizing a single well’s IP can unintentionally cannibalize its neighbors through pressure depletion, stress shadowing, and fracture interference.
The unconventional wisdom is clear: plan integrated pad development from the outset, balancing spacing, sequencing, and timing across all wells.
Simulation: Your Pad Planning Power Tool
This is where advanced pad-level simulation changes the game.
Simulation allows teams to model dozens of wells simultaneously, across stacked zones, capturing complex pressure interactions and depletion shadows before a single well is drilled.
Questions that once required costly pilots or trial-and-error can now be tested virtually:
- How tight is too tight for spacing in this formation?
- What happens if we stagger drilling over time?
- Does a different completion sequence reduce interference?
Simulation provides data-driven answers.
Designing a pad no longer depends on intuition or hindsight. Teams can iterate virtually, balancing well count against per-well performance, aligning laterals to minimize fracture overlap, and scheduling fracs to avoid excessive pressure sinks.
The result is a development strategy that maximizes value from the entire pad, not just one star well.
In short, treat the pad as the unit of design and use simulation to make every well work together, not against each other.
