Bubble Point Pressure Calculator
Estimate bubble point pressure (Pb) using Standing's correlation. Enter API gravity, solution GOR, gas gravity, and reservoir temperature.
Input Parameters
Pb = 18.2 × [(Rs/γg)^0.83 × 10^a - 1.4]
where a = 0.00091×T - 0.0125×API
Bubble Point Pressure
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psia
Bubble Point (bar)
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bar
Bubble Point (kPa)
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kPa
How this was calculated
Standing Correlation (1947): One of the most widely used correlations for estimating bubble point pressure of crude oil systems.
Formula: Pb = 18.2 × [(Rs / γg)^0.83 × 10^(0.00091×T - 0.0125×API) - 1.4]
Applicability: California crude oils; works well for API 16-63, GOR 20-1820 scf/STB, T 100-258°F, γg 0.59-0.95.
Reference: Standing, M.B. (1947). "A Pressure-Volume-Temperature Correlation for Mixtures of California Oils and Gases."
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Book a free strategy call →Understanding Bubble Point Pressure
Bubble point pressure (Pb) is the pressure at which the first gas bubble forms in an undersaturated oil as pressure is reduced at constant reservoir temperature. It is one of the most critical parameters in reservoir engineering, directly affecting material balance calculations, well performance predictions, and reserves estimates.
Standing's correlation (1947) is an empirical method that estimates Pb from four readily available parameters: solution gas-oil ratio (Rs), gas specific gravity, oil API gravity, and temperature. While developed for California crudes, it remains widely used as a screening tool and initial estimate across global basins.
For production planning, knowing the bubble point helps determine whether a reservoir is undersaturated or saturated, which controls drive mechanisms, recovery factors, and artificial lift requirements. All calculations run entirely in your browser with no data sent to any server. Built by Groundwork Analytics.