Pore Capillary Pressure Determination for Oil/Gas Facility Optimization
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Solution Overview
Problem
Current methods for determining pore capillary pressure in oil/gas reservoirs are inaccurate, leading to suboptimal fluid recovery due to reliance on core sample calculations that do not reflect in-reservoir conditions, and thus fail to adequately account for fluid saturation pressure and phase behavior.
Innovation Solution
A method involving a computer-readable medium with instructions to determine pore capillary pressure and PVT parameters based on input data characterizing condensate and gas phase components, allowing for adjustments in oil/gas facility settings to optimize fluid recovery, including calculations for vaporized oil-gas ratio, solution-gas ratio, and formation volume factors as functions of pressure and pore throat radius.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If capillary pressure is calculated from core samples using industry standard methods, then the calculation process is simple and straightforward, but the accuracy of capillary pressure determination deteriorates because core sample calculations do not reflect in-reservoir conditions
Solution Approach 1:
The patent replaces the mechanical/core-based determination method with a computational approach using mathematical models and simulations. The system uses phase behavior data, PVT parameters, and numerical simulations to calculate capillary pressure, substituting physical core sample analysis with computer-based modeling that can account for in-reservoir conditions without requiring additional physical measurements.
Solution Approach 2:
The patent introduces intermediate computational parameters and models as mediators between available field data and capillary pressure determination. By using phase behavior models, PVT parameters, and numerical simulations as intermediaries, the system translates readily available operational data into accurate capillary pressure values that reflect actual reservoir conditions.
2Productivity
If accurate pore capillary pressure determination is implemented, then fluid recovery optimization improves, but the complexity of facility control settings increases
Solution Approach 1:
The patent implements a feedback mechanism where capillary pressure determination results are continuously used to adjust facility control settings. The system monitors phase behavior, updates PVT parameters, and modifies separation and production facility operations based on the determined capillary pressure values, creating a closed-loop control system that optimizes fluid recovery while managing complexity through automated adjustment.
Solution Approach 2:
The patent makes the facility control settings dynamic by linking them to the determined capillary pressure values. Instead of static operating parameters, the system continuously adjusts separation settings, production rates, and facility operations based on real-time capillary pressure determination, allowing the control system to adapt to changing reservoir conditions and optimize recovery throughout the production lifecycle.
3Measurement precision
If conventional PVT parameter calculations are used without capillary pressure consideration, then the calculation process is simpler, but the accuracy of phase behavior prediction deteriorates
Solution Approach 1:
The patent performs preliminary determination of capillary pressure and PVT parameters before they are needed for facility control decisions. By pre-calculating these parameters using phase behavior models and numerical simulations, the system has accurate data ready for immediate use in optimization, eliminating the need for time-consuming calculations during critical decision-making periods while maintaining high accuracy.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
This approach enables accurate determination of PVT parameters, allowing for optimized control of oil/gas facility settings, improving fluid recovery by accounting for capillary pressure effects on phase behavior and reservoir conditions, leading to enhanced condensate and gas production.
Implementation Method 1
determining a pore capillary pressure of the reservoir based on the received input data which characterizes the phase components
Implementation Method 2
determining PVT parameters of the reservoir phase components based on the determined pore capillary pressure
Data Source
AI summary
A computerized method and system for of operating an oil/gas facility for processing oil and gas from a reservoir. The method includes steps of receiving input data concerning condensate phase and gas phase components in the reservoir, the input data characterizing both phase components, determining a pore capillary pressure of the reservoir based on the received input data which characterizes the phase components, determining PVT parameters of the reservoir phase components based on the determined pore capillary pressure, and controlling a setting of the oil/gas facility based on the determined PVT parameters of the reservoir phase components.