Three-Phase Fluid Saturation Determination from Well Measurements
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Solution Overview
Problem
Accurately determining three-phase fluid saturations (oil, water, and gas) in subsurface hydrocarbon reservoirs is challenging due to complexity and variability, requiring costly and time-consuming historical data and numerical modeling.
Innovation Solution
A method using real-time production rate and pressure measurements from production wells to calculate three-phase saturations without historical datasets or numerical models, employing fractional flow calculations and PVT properties to determine oil, water, and gas saturations directly.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If historical data and numerical modeling are used to determine three-phase fluid saturations, then measurement precision is improved, but loss of time and loss of substance increase
Solution Approach 1:
The patent extracts and utilizes only the essential real-time measurements (production rates and bottomhole pressures) from the complex reservoir system, eliminating the need for extensive historical datasets and complex numerical models. This extraction approach maintains measurement precision by focusing on the most critical parameters while significantly reducing time investment.
Solution Approach 2:
The method employs readily available, inexpensive real-time production data and pressure measurements instead of costly, time-consuming historical datasets and extensive numerical modeling efforts. These short-term measurements are sufficient to determine three-phase saturations without requiring long-term data accumulation.
2Measurement precision
If historical data and numerical modeling are used to determine three-phase fluid saturations, then measurement precision is improved, but loss of substance increases
Solution Approach 1:
The reservoir system itself provides the necessary information through its normal production process. Real-time production rates and bottomhole pressures are automatically recorded during routine operations, eliminating the need for separate, costly data collection campaigns and extensive historical data gathering efforts.
Solution Approach 2:
The method utilizes inexpensive, readily available real-time operational data instead of costly historical datasets and extensive numerical modeling resources. This approach significantly reduces substance loss by leveraging data that is already being collected during normal production without requiring additional investment in data acquisition infrastructure.
3Measurement precision
If conventional methods are used to determine three-phase saturations, then measurement precision is improved, but device complexity increases
Solution Approach 1:
The patent extracts only the essential measurements (production rates and bottomhole pressures) needed for saturation determination, eliminating the complexity of processing extensive historical datasets and running complex numerical models. This extraction strategy maintains measurement precision while dramatically simplifying the data processing system.
Solution Approach 2:
Instead of using complex numerical models to predict saturations from limited data, the method inverts the approach by directly calculating saturations from simple real-time measurements using established relationships. This inversion simplifies the computational complexity while maintaining or improving measurement precision.
Data Source
AI summary
The determination of subsurface three-phase saturation (that is, oil, water, and gas saturation) across perforations and open completions of production wells using production rates and pressure measurements. A process may use the surface production rates of oil, water, and gas and measured pressures to determine well fractional flows. The subsurface three-phase saturation may be determined using the cell fractional flows calculated from the well fractional flows. Computer-readable media and systems for determining subsurface three-phase saturation are also provided.