logo Inflow Performance Relationship Calculator


Well Information

Well Name
Lift Type
Current Pump Depth ft TVD
Bottom Perf Depth ft TVD

Reservoir Fluid & Reserves

Initial Reservoir Pressure psi
Abandoned Reservoir Pressure psi
EUR Oil Mbbls
Cumulative to Date Oil Mbbls
Pmax (bubble point pressure) psi
Oil API deg deg
Oil SG frac frac
Dimensionless Oil Recovery %
GOR current scf/bbl
Water SG frac
Water Cut %

Current Reservoir Pressure

Static FL above pump ft TVD
SI Static CSG Pressure psi
FL Calc Reservoir Pressure psi
P50 Est Reservoir Pressure psi
P10 Est Reservoir Pressure psi
P90 Est Reservoir Pressure psi
Chosen for Analysis

Note ▼
SI Well along w/CSG line for 1 to 2 days minimum to attain. At end of SU make sure to record CSG line pressure & shoot fluid level

Pumping Data

Current FL Above Pump ft TVD
CSG Pressure psi
Q water current bpd
Q oil current bpd
Q gas current mscf/d
Pwf current psi
Q/Qmax current (oil) frac
Qmax oil (theoretical) bpd

Note ▼ am206830: Allow well to pump normally for at minimum 3 to 4 days. Keep GSC line open if possible. Perform new well test if possible (or use existing allocated) & record CSG line pressure (whether it is open or shut-in). Note that of there is a GSC gas recovery but gas prod rate from well is not recorded there will be extra errors built into estimation
  • Current FL Above Pump: enter Fluid Over PERFS if pump is raised above

Chart Curve Data

Y-Intercept chart
Pwf/Pmax chart
Fraction (X-Intercept) chart

Normalized Vogel Plot

Desired Pumping Conditions

Target FOPump TVD ft
Target FOPerf TVD ft
Target Pump Depth TVD ft
Target CSG P. Psi
Delta Perf & Pump TVD ft
Pwf after psi
Pwf/Pmax after frac
Q/Qmax after (oil) frac
Q max oil (actual) bpd

Note ▼ Optimal pumping conditions are FOP as low as possible & CSG line pressure as low as possible.
  • Target FOPump: With Rod well this target should be ZERO,(i.e. PUMP OFF). Even if a unit cannot handle pump depth & fluid rate a pump can be raised to allow for pump off shallower in trade off for overall higher production & net gain in drawdown
  • Target FOPerf: This value has to be between Target Pump Depth & Delta Perf & Pump TVD Values.

Uplift Potential

Delta Q/Qmax (oil) frac
Inc Oil Prod BPD
Inc Water Prod BPD
Inc Gross Liq Prod BPD
Inc Gas Prod Mscf/D
Q Oil after BPD
Q Water after BPD
Q Gas after Mscf/D
Q Gross Liq after BPD

Note ▼ Use Q gross after to figure pump size & make sure to take into consideration what lift limitations are, eg, pumping unit may not be able to handle pump size at current depth to get extra Production
  • Inc Oil Prod this is economic value of drawdown

Rod Pump Estimator

Runtime hrs
Efficiency %

SL (in)SPMPD (in)BGPD%Q after
Vary Stroke
Vary SPM
Vary Pump

Note ▼ Optimal situation is to have a pump that can handle 100% Q after at 17-24 hr runtime.

  • Runtime: best runtimes are between 17 & 22 hrs
  • Efficiency: default value best to use is 85%
  • Variable Stroke:am206830: Make sure to check if unit has extra stroke length available & if gearbox can handle longer stroke. If rodstar can be used this value would be better since it is best to enter down-hole effective stroke rather than surface stroke length
  • Variable SPM:am206830: Make sure to check of if unit has Jack-Shafts installed
  • Variable Pump Size:am206830: This program doesn't account for pump size restrictions. This variable is probably the best to take advantage of but may involve other equipment changes (i.e. TBG, On/Off Tools, etc.)

Composite IPR Plot

Predicted Rates

Well Name
# Pressure Data Points
Press Increment (approx) psi
Current Res Presssure psi
PI (Water Production) frac

Note ▼ Optimal pumping conditions are FOP as low as possible & CSG line pressure as low as possible
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