Petroleum Well Test Dual Porosity Lambda Calculator
Explicit Warren–Root λ=α rw² km/kf with independent block shape factorα in m⁻², not guessed cubic-block factor or automatic type-curve fitting. Caller independently verifies units, applicability and matching conditions; no operational recipe, safety certification, causal efficacy or legal/resource classification is inferred.
Description
Warren–Root interporosity lambda combines matrix-to-fracture permeability with a block shape factor and wellbore radius.
Warren–Root interporosity lambda combines matrix-to-fracture permeability with a block shape factor and wellbore radius.1
This calculator requires those independent quantities and their SI units rather than fitting them from a type curve.
When to use Petroleum Well Test Dual Porosity Lambda 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 Well Test Dual Porosity Lambda 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 callerIndependentMatrixShapeFactorsPerM2, observedWellboreRadiiM, callerMatchedMatrixPermeabilitiesM2, callerMatchedFracturePermeabilitiesM2, following the field table and calculation rules below, then run the tool.
- Read callerWarrenRootInterporosityLambda. 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 |
|---|---|---|---|
| callerIndependentMatrixShapeFactorsPerM2 | Caller independent matrix shape factors per m2 | list of number | Required |
| observedWellboreRadiiM | Observed wellbore radii m | list of number | Required |
| callerMatchedMatrixPermeabilitiesM2 | Caller matched matrix permeabilities m2 | list of number | Required |
| callerMatchedFracturePermeabilitiesM2 | Caller matched fracture permeabilities m2 | list of number | Required |
Require nonempty aligned strictly positive shape factors in m⁻², radii in metres, and matrix/fracture permeabilities in m². Multiply shape factor by radius squared and matrix permeability, then divide by fracture permeability for each row. No block geometry factor is inferred.
lambda=alphaPerM2×radiusM²×matrixPermeabilityM2/fracturePermeabilityM2 Read these symbols with the field meanings and branch or reference rules above.
| Output field | Meaning | Value type |
|---|---|---|
| callerWarrenRootInterporosityLambda | Caller warren root interporosity lambda | list of number |
{
"input": {
"callerIndependentMatrixShapeFactorsPerM2": [
2,
4
],
"observedWellboreRadiiM": [
1,
2
],
"callerMatchedMatrixPermeabilitiesM2": [
1,
1
],
"callerMatchedFracturePermeabilitiesM2": [
10,
20
]
},
"output": {
"callerWarrenRootInterporosityLambda": [
0.2,
0.8
]
}
}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 Well Test Dual Porosity Omega Calculator: Dual-porosity storage ratio omega compares fracture storage with the total fracture-plus-matrix storage. This calculator uses independently established storage quantities, which are not interchangeable with geometric pore-volume fractions. For a complementary step, use Petroleum Type Curve Match Calculator: A type-curve comparison needs an independently aligned time basis and an explicit normalization. This matcher fits one vertical log scale and summarizes shape residuals, without moving the curve horizontally or identifying a reservoir regime.
References
Similar or alternative tools
- Petroleum Well Test Dual Porosity Omega Calculator
Dual-porosity storage ratio omega compares fracture storage with the total fracture-plus-matrix storage. This calculator uses independently established storage quantities, which are not interchangeable with geometric pore-volume fractions.
- Petroleum Type Curve Match Calculator
A type-curve comparison needs an independently aligned time basis and an explicit normalization. This matcher fits one vertical log scale and summarizes shape residuals, without moving the curve horizontally or identifying a reservoir regime.