Petroleum Material Balance Oil Calculator
Explicit reduced solution-gas oil balance N=(Np[Bo+(Rp−Rs) Bg]+WpBw−We)/[Bo−Boi+(Rsi−Rs) Bg], no gas-cap, injection or rock/water compressibility terms; caller matches reservoir/stock units, signed inconsistency retained. Caller independently verifies units, applicability and matching conditions; no operational recipe, safety certification, causal efficacy or legal/resource classification is inferred.
Description
A reduced solution-gas oil material balance compares measured withdrawal and modeled fluid expansion on a matched stock/reservoir basis.
A reduced solution-gas oil material balance compares measured withdrawal and modeled fluid expansion on a matched stock/reservoir basis.1
This calculator exposes that reduced model and retains signed inconsistencies rather than implying a complete reservoir balance.
When to use Petroleum Material Balance Oil 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 Material Balance Oil 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 observedProducedStockOilM3, observedTotalProducedGasPerOilStockRatio, callerCurrentSolutionGasOilRatio, callerInitialSolutionGasOilRatio, callerCurrentOilFvf, callerInitialOilFvf, callerCurrentGasFvf, observedProducedStockWaterM3, callerWaterFvf, callerIndependentWaterInfluxReservoirM3, following the field table and calculation rules below, then run the tool.
- Read reducedOilMaterialBalanceOriginalStockOilM3. 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 |
|---|---|---|---|
| observedProducedStockOilM3 | Observed produced stock oil m3 | number | Required |
| observedTotalProducedGasPerOilStockRatio | Observed total produced gas per oil stock ratio | number | Required |
| callerCurrentSolutionGasOilRatio | Caller current solution gas oil ratio | number | Required |
| callerInitialSolutionGasOilRatio | Caller initial solution gas oil ratio | number | Required |
| callerCurrentOilFvf | Caller current oil fvf | number | Required |
| callerInitialOilFvf | Caller initial oil fvf | number | Required |
| callerCurrentGasFvf | Caller current gas fvf | number | Required |
| observedProducedStockWaterM3 | Observed produced stock water m3 | number | Required |
| callerWaterFvf | Caller water fvf | number | Required |
| callerIndependentWaterInfluxReservoirM3 | Caller independent water influx reservoir m3 | number | Required |
Require positive current/initial oil FVF, current gas FVF, and water FVF, with nonnegative stock production volumes, gas-oil ratios, and independent reservoir water influx. Compute expansion Bo−Boi+(Rsi−Rs)Bg and require it strictly positive. Compute Np[Bo+(Rp−Rs)Bg]+WpBw−We, retain its sign, and divide by expansion. Gas-cap, injection, and rock/water-compressibility terms are absent.
N=(Np[Bo+(Rp−Rs)Bg]+WpBw−We)/(Bo−Boi+(Rsi−Rs)Bg) Read these symbols with the field meanings and branch or reference rules above.
| Output field | Meaning | Value type |
|---|---|---|
| reducedOilMaterialBalanceOriginalStockOilM3 | Reduced oil material balance original stock oil m3 | number |
{
"input": {
"observedProducedStockOilM3": 10,
"observedTotalProducedGasPerOilStockRatio": 2,
"callerCurrentSolutionGasOilRatio": 1,
"callerInitialSolutionGasOilRatio": 2,
"callerCurrentOilFvf": 2,
"callerInitialOilFvf": 1,
"callerCurrentGasFvf": 0.1,
"observedProducedStockWaterM3": 3,
"callerWaterFvf": 1,
"callerIndependentWaterInfluxReservoirM3": 5
},
"output": {
"reducedOilMaterialBalanceOriginalStockOilM3": 17.27272727272727
}
}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.
Alternative or Complementary methods
For a related task, use Petroleum Original Oil In Place OOIP Calculator: Original in-place stock volume can be estimated by summing independently delineated reservoir patches. This oil calculator uses area, net thickness, porosity, water saturation, and a matched formation-volume factor for each nonoverlapping patch. For a complementary step, use Petroleum Material Balance Gas Calculator: For a verified closed dry-gas balance, pressure divided by gas Z factor can be fitted against cumulative stock production. This tool uses the supplied Z observations and extrapolated line intercept to calculate the reduced balance’s original gas volume.
References
Similar or alternative tools
- Petroleum Original Oil In Place OOIP Calculator
Original in-place stock volume can be estimated by summing independently delineated reservoir patches. This oil calculator uses area, net thickness, porosity, water saturation, and a matched formation-volume factor for each nonoverlapping patch.
- Petroleum Material Balance Gas Calculator
For a verified closed dry-gas balance, pressure divided by gas Z factor can be fitted against cumulative stock production. This tool uses the supplied Z observations and extrapolated line intercept to calculate the reduced balance’s original gas volume.