Petromium Tools / Formula set IPR-001
Oil-Well Inflow Performance
Linear PI · Vogel · composite inflow · browser-only workspace · V2.0
Rate versus flowing bottomhole pressure
Inflow performance curves
Oil rate against flowing bottomhole pressure
1 reservoir-pressure case(s) · composite inflow
Figure data
| Case | Reservoir pressure (MPa a) | Model | Theoretical max rate (m³/day) | Curve points |
|---|---|---|---|---|
| Current reservoir pressure | 27.579 | composite | 918.593 | 25 |
Measured points are drawn as open rings; their residuals against the fitted inflow are listed in the results panel.
Pressure path
Reservoir-to-sandface
Reservoir to sandface pressure
Drawdown 17.24 MPa · 37.5% of reservoir pressure remaining at the sandface
Reservoir pressure
27.579 MPa(a)
Drawdown
17.237 MPa
Figure data
| Quantity | Value |
|---|---|
| Reservoir pressure (MPa a) | 27.579 |
| Flowing bottomhole pressure (MPa a) | 10.3421 |
| Drawdown (MPa) | 17.2369 |
Model and calibration
Linear above bubblepoint, slope-continuous Vogel below. Calibration never selects a completion or operating target.
Absolute pressures and declared calibration
Inflow inputs
Calculation complete
Calculation audit
Rate at pwf
4,644.444 STB/d
Calibrated PI
2 STB/d/psi
Drawdown
2,500 psia
Theoretical zero-pwf
5,777.778 STB/d
Calculation observations
The maximum rate is the mathematical zero-flowing-pressure endpoint of the selected IPR, not an operating target or absolute open-flow authorization.
Steady single-completion screening only; transient inflow, multilayer crossflow, fractures, coning, water-cut effects, and automatic operating-point selection are excluded.
Named local cases
Browser snapshots
Save a snapshot to restore an entered IPR case on this device.
Screening scope
Model boundary
Selected model
Composite
Curve cases
1
Measured points
0
Included: single-completion steady inflow with explicit calibration.
Excluded: transient, fractured/horizontal, multilayer, coning, water-cut, and automatic operating-point selection.