Petroleum Relative Permeability Krg Calculator
Infer actual gas phase relative permeability from matched Darcy core-flow/viscosity/geometry, independently established absolute permeability and net potential drop; negative/>1 apparent measurement evidence retained, no saturation law or experiment recipe. Caller independently verifies units, applicability and matching conditions; no operational recipe, safety certification, causal efficacy or legal/resource classification is inferred.
Description
Relative permeability compares a phase’s effective flow capacity with an independently measured absolute permeability.
Relative permeability compares a phase’s effective flow capacity with an independently measured absolute permeability.1
This gas tool inverts matched core-flow observations and retains signed or above-one apparent results for review.
When to use Petroleum Relative Permeability Krg Calculator
Use this tool when you need to calculate the stated measurement summary or conditional model from matched observations. Prepare completed matched measurements, SI or explicitly stated oilfield units, and independent evidence for the selected branch or calibration.
How to use Petroleum Relative Permeability Krg Calculator and understand its results
- Prepare completed matched measurements, SI or explicitly stated oilfield units, and independent evidence for the selected branch or calibration.
- Enter observedGasPhaseFlowM3Second, observedGasPhaseViscosityPaSeconds, observedGasCoreLengthsM, callerMatchedGasAbsolutePermeabilityM2, observedGasCoreAreasM2, observedGasNetPotentialDropsPa, following the field table and calculation rules below, then run the tool.
- Read apparentObservedPhaseRelativePermeabilities. For result objects, inspect the nested output fields below, including any missing evidence or selected indices.
- Correct any input issues and run again. Before using a successful result, review its units, signs, evidence coverage, and stated model or reference assumptions.
| Input field | Meaning | Value type | Requirement |
|---|---|---|---|
| observedGasPhaseFlowM3Second | Observed gas phase flow m3 second | list of number | Required |
| observedGasPhaseViscosityPaSeconds | Observed gas phase viscosity pa seconds | list of number | Required |
| observedGasCoreLengthsM | Observed gas core lengths m | list of number | Required |
| callerMatchedGasAbsolutePermeabilityM2 | Caller matched gas absolute permeability m2 | list of number | Required |
| observedGasCoreAreasM2 | Observed gas core areas m2 | list of number | Required |
| observedGasNetPotentialDropsPa | Observed gas net potential drops pa; pressure or stress in pascals, with the sign convention described above. | list of number | Required |
Require nonempty aligned gas flow values in m³/s and positive viscosities, core lengths, absolute permeabilities, areas, and net potential drops in the stated SI units. Flow is finite signed input. Compute qμL/(kAbsolute A Δpotential) for each row, without clamping apparent relative permeability to [0,1].
kr_app=qμL/(k_absolute A Δpotential) Read these symbols with the field meanings and branch or reference rules above.
| Output field | Meaning | Value type |
|---|---|---|
| apparentObservedPhaseRelativePermeabilities | Apparent observed phase relative permeabilities | list of number |
{
"input": {
"observedGasPhaseFlowM3Second": [
1,
2
],
"observedGasPhaseViscosityPaSeconds": [
1,
1
],
"observedGasCoreLengthsM": [
1,
1
],
"callerMatchedGasAbsolutePermeabilityM2": [
1,
1
],
"observedGasCoreAreasM2": [
1,
1
],
"observedGasNetPotentialDropsPa": [
2,
4
]
},
"output": {
"apparentObservedPhaseRelativePermeabilities": [
0.5,
0.5
]
}
}Limitations and assumptions
Measurements, unit conventions, branch identity, and model applicability must be independently established. The result does not infer a complete reservoir or flow model, operational settings, or a reserve classification.
Missing required fields, unknown fields, wrong types, and violated calculation rules return input issues. Numeric values must be finite; nonfinite numeric outputs are rejected. Arrays must be dense, with no missing cells. Numeric lists allow at most 10000 entries, subject to smaller tool-specific bounds above.
Alternative or Complementary methods
For a related task, use Petroleum Relative Permeability Krw Calculator: Relative permeability compares a phase’s effective flow capacity with an independently measured absolute permeability. This water tool inverts matched core-flow observations and retains signed or above-one apparent results for review. For a complementary step, use Petroleum Mobility Ratio Calculator: Mobility combines relative permeability and viscosity under a matched displacement-front basis. This calculator compares the displacing phase’s mobility with that of the displaced phase rather than using viscosity ratio alone.
References
Similar or alternative tools
- Petroleum Relative Permeability Krw Calculator
Relative permeability compares a phase’s effective flow capacity with an independently measured absolute permeability. This water tool inverts matched core-flow observations and retains signed or above-one apparent results for review.
- Petroleum Mobility Ratio Calculator
Mobility combines relative permeability and viscosity under a matched displacement-front basis. This calculator compares the displacing phase’s mobility with that of the displaced phase rather than using viscosity ratio alone.