Technical resources
Practical articles about drilling data architecture, statistics, engineering models, real-time systems, directional work, and applied AI.
Slide and rotate are different operating populations. Compare mode-specific ROP, time, footage, bit RPM, weight transfer, and directional burden before judging a section.
Read article →Surface WOB, RPM, and torque are not direct bit measurements. Friction, axial transfer, mud motors, trajectory, state, and model calibration separate them.
Read article →Formation changes confound ROP, MSE, torque, and directional comparisons. Detect transitions, rebaseline locally, and use formation-matched evidence without over-attribution.
Read article →WOB-RPM response is nonlinear, local, and constrained. Prefer a well-supported operating region over a precise optimum inferred from sparse or mixed-context data.
Read article →MSE relates mechanical input to rock removal, but high MSE does not identify a unique cause. Diagnose departures with formation, state, dynamics, and supporting channels.
Read article →High ROP is an outcome, not a complete diagnosis. Judge it with MSE, drilling dynamics, bit condition, hole cleaning, wellbore quality, and repeatability.
Read article →Invisible lost time is the repeatable gap between actual and achievable routine work. Segment events, use defensible benchmarks, and rank total opportunity.
Read article →A useful offset benchmark matches the engineering question, coordinate, formation, rig state, BHA, bit, measurement basis, and current-well evidence.
Read article →A benchmark is trustworthy only when its population, independent unit, measurement method, weighting, dispersion, selection, and recency fit the decision.
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