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Well performance
operating point, forecast & pump curves—
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Pump H-Q curve
string head vs system demand
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Nodal analysis
IPR inflow vs pump outflow
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Wellbore & schematic
full-depth well state & pressure traverseWell schematic
Pump
Separator
Seal
Motor
Oil
Water
Free gas
Engineering charts
pump section performance, pressure traverse & electricalMotor & electrical
load, power and cable at operating point
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ESP landing & run-in-hole
survey-driven setting-depth advisor & bending-stress checkDirectional survey
Paste three columns: MD · Inclination · Azimuth
one station per line — a header row is auto-detected, extra columns (TVD, N/S…) are ignored,
and comma, tab or space separated all work (thousands separators like 1,500 are fine)
No survey loaded
Casing / liner strings
| Size (OD · weight) | Top MD | Btm MD |
|---|
DLS & bending limits
Landed = the dogleg the string SITS in; kept low (~2°) so the rotating shaft & couplings don't fatigue. Run-in = the sharpest dogleg it PASSES THROUGH (transient — recommend ≤6°, run to ≤12°), bounded by the housing-neck bending surviving the bend (carbon-steel E = 30×10⁶ psi). The string is modeled as rigid housings (pumps · separator 4.5′ · seal 6′ · motor) that bend at the flanged necks between them. Pump stiffening % credits the shaft/stage stack's added bending stiffness (motors, seals & separators use fixed built-in assumptions). Extra weight below motor adds hanging-weight (axial tension) from anything hung off the motor's bottom — a desander, sensor sub, etc. — that isn't otherwise modeled. Risk line is the working limit that pass/fail checks are graded against (default 25,000 psi — real bolted-flange necks usually fail at the bolts, not the tube section this model computes, and bolt count/metallurgy varies by vendor, so treat this as adjustable). Yield line is a second, more severe reference only (default 44,000 psi, from real field bending-failure data) shown on the charts for context — it does not gate any checklist result.
1
Paste a directional surveyMD · Inclination · Azimuth — straight from Excel or a CSV upload. A header row is detected automatically.
2
Confirm casing & limitsCasing/liner strings, top perf, and (optionally) the DLS & bending limits.
3
Analyze landingGet a recommended setting depth (run-in ≤6° DLS) and the deepest the string survives (≤12° or neck bending), plus a grade of your current set depth.
Well schematic
straightened vertical — casing · tubing · ESP string & accessoriesESP string
Housing split — stages per bolted housing, top → bottom
Pumps, stages, separator & motor come from the current scenario design (sidebar). Each pump is pre-filled with the split its catalog housing sizes give; edit a row to override. Every extra housing is a real bolted neck the bending model checks, so the split changes the answer.
Above the pump — in the tubing, above discharge
Below the motor
Tubing stretch & hang load
Amber/red bands on the overview mark survey intervals above 3° / 6° DLS (×uplift when checked) — slow the RIH speed through those (table below the drawing). A 3′ sensor is always modeled on the motor base (bolted — bending-checked); everything below it (desander · tailpipe · no-go) hangs on THREADED connections, so it loads the string as weight only. Hang load is buoyed in the produced brine and includes the banded cable. The safety factor applies to the service loads; the overpull case is checked unfactored — the allowance is the margin, and stacking both double-counts contingency (industry tension DF range 1.25–1.6, 1.3 typical).