Petroleum Type Curve Match Calculator
Fit actual caller independently time-aligned type curve vertical log-scale and shape residual, no inferred time shift, reservoir regime identity or permeability from unspecified normalization. Caller independently verifies units, applicability and matching conditions; no operational recipe, safety certification, causal efficacy or legal/resource classification is inferred.
Description
A type-curve comparison needs an independently aligned time basis and an explicit normalization.
A type-curve comparison needs an independently aligned time basis and an explicit normalization.1
This matcher fits one vertical log scale and summarizes shape residuals, without moving the curve horizontally or identifying a reservoir regime.
When to use Petroleum Type Curve Match 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 Type Curve Match 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 observedAlignedTypeCurvePressures, callerMatchedDimensionlessTypeCurveValues, callerMaximumLogShapeRmse, following the field table and calculation rules below, then run the tool.
- Read fittedTypeCurveVerticalPressureScale, logShapeRmse, withinCallerTypeCurveShapeTolerance. 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 |
|---|---|---|---|
| observedAlignedTypeCurvePressures | Observed aligned type curve pressures | list of number | Required |
| callerMatchedDimensionlessTypeCurveValues | Caller matched dimensionless type curve values | list of number | Required |
| callerMaximumLogShapeRmse | Caller maximum log shape rmse | number | Required |
Require nonempty aligned positive observed pressures and positive matched dimensionless curve values plus a nonnegative log-shape RMSE tolerance. Compute ln(observed)−ln(reference) for each pair, average, exponentiate for the scale, and take root mean square residual about that average. Compare RMSE≤tolerance inclusively. A single pair fits exactly and is allowed.
scale=exp(mean(ln(P_i)−ln(type_i))); RMSE=sqrt(mean((logRatio_i−meanLogRatio)²)) Read these symbols with the field meanings and branch or reference rules above.
| Output field | Meaning | Value type |
|---|---|---|
| fittedTypeCurveVerticalPressureScale | Fitted type curve vertical pressure scale | number |
| logShapeRmse | Log shape rmse | number |
| withinCallerTypeCurveShapeTolerance | Within caller type curve shape tolerance | boolean |
{
"input": {
"observedAlignedTypeCurvePressures": [
2,
4,
8
],
"callerMatchedDimensionlessTypeCurveValues": [
1,
2,
4
],
"callerMaximumLogShapeRmse": 0.1
},
"output": {
"fittedTypeCurveVerticalPressureScale": 2,
"logShapeRmse": 6.409875621278546e-17,
"withinCallerTypeCurveShapeTolerance": true
}
}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 Well Test Dual Porosity Lambda Calculator: Warren–Root interporosity lambda combines matrix-to-fracture permeability with a block shape factor and wellbore radius. This calculator requires those independent quantities and their SI units rather than fitting them from a type curve.
References
-
Petroleum Type Curve Match Calculator — tool.io
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 Well Test Dual Porosity Lambda Calculator
Warren–Root interporosity lambda combines matrix-to-fracture permeability with a block shape factor and wellbore radius. This calculator requires those independent quantities and their SI units rather than fitting them from a type curve.