Wellbore Genius
Pad optimisation — cost vs rate
Rows are pads, columns are pump rates. Each cell re-solves that pad's column at that rate and costs it, so you can see what a rate costs and how much fracture margin it leaves in the same place. Nothing is corrected for you: a pad that is not physical is refused with the reason, and a rate that will not solve is withheld rather than shown as zero.
Rate axis
The pump rates every pad is evaluated at, from 1 to 3000 gpm. Up to 12 columns.
Pads
Each pad is one hydraulic column from surface to total depth — that is what makes pads comparable on a single rate axis. Per-string detail belongs in the well database and the column calculator.
Cost vs rate grid
Pad cost, ECD, fracture headroom and the gradient ratio at every rate. 24 cells · 11 safe · 4 past the fracture limit · 0 withheld.
Cheapest safe: Ranger pad (shallow) at 400 gpm · $4,805 for the pad
4.19 ppg below the fracture gradient · ratio 0.71| Pad | 150 gpm3.6 bpm | 200 gpm4.8 bpm | 250 gpm6.0 bpm | 300 gpm7.1 bpm | 350 gpm8.3 bpm | 400 gpm9.5 bpm | 450 gpm10.7 bpm | 500 gpm11.9 bpm |
|---|---|---|---|---|---|---|---|---|
Ranger pad (shallow) 4 wells · 8,200 ft TD · 9.80 ppg · pore 8.60 / frac 14.60 ppg · 150 psi surface Cheapest safe 400 gpm · $4,805 | $12,706 ECD 10.37 ppg 4.23 ppg margin ratio 0.71 Safe | $9,545 ECD 10.38 ppg 4.22 ppg margin ratio 0.71 Safe | $7,648 ECD 10.38 ppg 4.22 ppg margin ratio 0.71 Safe | $6,384 ECD 10.39 ppg 4.21 ppg margin ratio 0.71 Safe | $5,482 ECD 10.40 ppg 4.20 ppg margin ratio 0.71 Safe | $4,805 ECD 10.41 ppg 4.19 ppg margin ratio 0.71 Safe | $4,380 ECD 11.89 ppg 2.71 ppg margin ratio 0.81 Infeasible | $3,985 ECD 12.27 ppg 2.33 ppg margin ratio 0.84 Infeasible |
Midland pad (mid-depth) 6 wells · 10,500 ft TD · 10.50 ppg · pore 9.20 / frac 15.40 ppg · 250 psi surface Cheapest safe 350 gpm · $10,540 | $24,415 ECD 11.17 ppg 4.23 ppg margin ratio 0.73 Safe | $18,343 ECD 11.17 ppg 4.23 ppg margin ratio 0.73 Safe | $14,701 ECD 11.18 ppg 4.22 ppg margin ratio 0.73 Safe | $12,274 ECD 11.19 ppg 4.21 ppg margin ratio 0.73 Safe | $10,540 ECD 11.20 ppg 4.20 ppg margin ratio 0.73 Safe | $9,448 ECD 12.43 ppg 2.97 ppg margin ratio 0.81 Infeasible | $8,498 ECD 12.79 ppg 2.61 ppg margin ratio 0.83 Infeasible | $7,756 ECD 13.19 ppg 2.21 ppg margin ratio 0.86 Infeasible |
Deep HP/HT pad 3 wells · 15,800 ft TD · 13.40 ppg · pore 12.10 / frac 16.80 ppg · 700 psi surface No rate on this axis clears every limit for this pad — treat the whole row as not pumpable as entered. Within 5% of the fracture limit at 300 gpm — a small rate or mud-weight change could cross it. | $14,415 ECD 14.55 ppg 2.25 ppg margin ratio 0.87 Infeasible | $10,839 ECD 14.57 ppg 2.23 ppg margin ratio 0.87 Infeasible | $8,693 ECD 14.58 ppg 2.22 ppg margin ratio 0.87 Infeasible | $7,535 ECD 16.40 ppg 0.40 ppg margin ratio 0.98 Infeasible | $6,618 ECD 17.10 ppg 0.30 ppg over ratio 1.02 Past fracture limit | $5,970 ECD 17.88 ppg 1.08 ppg over ratio 1.06 Past fracture limit | $5,504 ECD 18.75 ppg 1.95 ppg over ratio 1.12 Past fracture limit | $5,170 ECD 19.70 ppg 2.90 ppg over ratio 1.17 Past fracture limit |
How to read this grid
The big number is the cost for the whole pad at that rate; hover a cell for the per-well cost, bottomhole pressure, friction, hours and pump duty. Margin is how much ECD headroom is left below the fracture gradient — a negative margin means the cell is over it. Ratio is the operating gradient divided by the fracture gradient: at 0.95 you are close, at 1.00 you are past it.
- Each cell is a full re-solve of that pad's column at that rate through the same solver the calculator and results page use — no interpolation between rates.
- Cost is circulating cost only: pump energy at the solved friction plus spread time for one bottoms-up. It excludes proppant, chemicals, mobilisation and any per-well fixed cost.
- A higher rate burns more pump power but finishes the bottoms-up sooner, so total circulating cost often falls as rate rises — the cheapest safe cell is not always the slowest one.
- Pad cost is the per-well cost multiplied by the wells on the pad; it assumes the wells are pumped one after another under the same spread rate.
- A pad is one hydraulic interval from surface to total depth, which is what makes pads comparable on one rate axis. Per-string detail belongs in the well database and the column calculator.
- Safe means the solver returned OK and the operating gradient stays below the fracture gradient AND the pad's required headroom is met — a row can be far from the fracture limit and still not safe (for example underbalanced against pore pressure).
Pad spacing & cluster density from the trained model
Takes the driver ranking of a model trained on your saved sweep results and lays its spacing suggestions out on this pad. Labelled ESTIMATE — a scan of the fitted model inside the ranges it was trained on, never a physics solve.
ESTIMATE
No trained model saved yet. Run a sweep in a workspace, enter the objective values, and train a model — the spacing suggestion appears here. Nothing is guessed in the meantime.
Stimulated probability — Pad optimization
GEOMETRY ONLY
Confidence that rock at each distance from the well was stimulated, from the fracture geometry and the barrier stress contrast. Not propped conductivity and not a measured volume.
Leave the observed extent blank to keep the shading uncalibrated — geometry only.
50% confidence at 800 ft10% confidence at 1503 fttip roll-off 320 ft
- Probability describes confidence that rock at that distance was stimulated — not propped conductivity and not a measured volume.
- Tip roll-off width is 320 ft, set by net pressure 600 psi against 900 psi of barrier contrast.
- Uncalibrated — geometry only. No field diagnostics are attached to this run, so the shading reflects the model's own tip, not observation.