Wellbore Genius

Downhole Simulator

Performance modeling

v1.0Solver: OK

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Downhole Dynamics Calculator

Enter depth, temperature, mud weight and wellbore pressure. Outputs hydrostatic, ECD, optimal mud-weight window, surface-pressure budget and breakdown margin.

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Inputs

Field units; values persist across sessions.

True vertical depth [ft]0–40000 ft

Calibration interval midpoint (typ. 2,000–25,000 ft)

Reservoir temperature [°F]32–600 °F

Static reservoir temp; typ. 80–400 °F

Observed wellbore pressure [psi]0–25000 psi

Measured/expected P_wh during pumping

Mud weight [ppg]7–22 ppg

Fresh water = 8.34 ppg; typ. 8.3–18 ppg

Pore pressure gradient [ppg]7–22 ppg

Normal ≈ 8.5; geopressured up to ~17 ppg-eq

Fracture gradient [ppg]8–25 ppg

Typ. 13–22 ppg-eq; must exceed pore gradient

Annular friction (ECD) [psi]0–5000 psi

Pressure drop returning up the annulus

Tubing / casing friction [psi]0–15000 psi

Pressure drop going down the pipe

BHP target [psi]0–25000 psi

Target bottomhole circulating pressure

Hydrostatic

5,088 psi

MW × 0.052 × TVD

ECD

9.97 ppg

with annular friction

Breakdown margin

5,181 psi

Est. P_bd ≈ 9,641 psi

Bottom-hole temp

170 °F

Geothermal est. 235 °F

Optimal mud-weight window

Pore + safety floor vs frac − safety ceiling.

Range: 8.90 – 17.50 ppgCurrent: 9.50 ppg

8.118.5 ppg

Margin to pore floor: 0.60 ppg

Margin to frac ceiling: 8.00 ppg

Surface-pressure budget

Max allowable surface P to hit BHP target.

Max surface P5,167 psi

Net above hydrostatic3,667 psi

BHP target8,755 psi

Pipe friction1,500 psi

Breakdown check

Observed P_wb vs gradient-based P_bd estimate.

Observed wellbore P4,460 psi

Estimated breakdown9,641 psi

Margin5,181 psi

Safe (below)

Engine: recommendPressures in src/lib/pressureAdvisor.ts. For depth-profile + scenario compare see Well calculator.