Wellbore Fluid Injection Using Relative Permeability Mapping
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Solution Overview
Problem
Existing hydrocarbon recovery techniques using water-alternating-gas injection face challenges in predicting fluid phase changes, which affect hydrocarbon recoverability and require complex interfacial tension modeling, especially when gas saturation data falls below trapped gas saturation thresholds.
Innovation Solution
Determine relative permeability of a subsurface formation by considering gas saturation data above or below trapped gas saturation thresholds, using equations to model drainage curves and adjust fluid injection phases, without accounting for interfacial tension, to better control hydrocarbon production and carbon dioxide sequestration.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If water-alternating-gas injection is used to extract hydrocarbons, then hydrocarbon recoverability is improved, but fluid phase changes occur unpredictably affecting recovery and requiring complex interfacial tension modeling
Solution Approach 1:
The patent extracts and focuses only on the essential parameter needed for fluid injection control - relative permeability data - while eliminating the need for complex interfacial tension modeling. By taking out the unnecessary complexity of full phase behavior modeling and concentrating on relative permeability as the key controlling parameter, the system achieves effective fluid injection control with simplified methodology.
Solution Approach 2:
The patent changes the approach from modeling interfacial tension and full phase behavior to using relative permeability data as the primary parameter for controlling fluid injection. This parameter change simplifies the complexity of the system while maintaining the ability to predict and control fluid phase changes and hydrocarbon recoverability.
2Measurement precision
If gas saturation data falls below trapped gas saturation thresholds, then accurate relative permeability determination becomes difficult, but hydrocarbon reserve estimation requires data across the full range of saturation values
Solution Approach 1:
The patent inverts the conventional approach by determining relative permeability data from gas saturation measurements taken during water-alternating-gas injection, rather than requiring traditional core flood experiments. This inversion allows relative permeability to be determined across the full range of gas saturation values, including below trapped gas saturation thresholds, thereby expanding the data range available for hydrocarbon reserve estimation while maintaining measurement precision.
Solution Approach 2:
The patent creates a universal methodology for determining relative permeability that works across all gas saturation conditions - above and below trapped gas saturation thresholds. This multi-functional approach allows the same measurement technique to provide accurate relative permeability data throughout the entire saturation range, enhancing both measurement precision and adaptability for reserve estimation.
3Reliability
If complex interfacial tension modeling is performed to account for phase changes, then fluid phase behavior is accurately predicted, but resource-intensive testing and modeling are required
Solution Approach 1:
The patent replaces expensive, resource-intensive interfacial tension modeling with a simpler, more economical approach using relative permeability data derived from gas saturation measurements. This substitution uses cheaper, more accessible data and methodology while maintaining the reliability needed for predicting fluid phase behavior and controlling injection operations.
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
Enhances the accuracy of hydrocarbon production control and carbon dioxide storage by providing a wider range of data for hydrocarbon reserve estimation and sequestration capacity, reducing the need for complex modeling and resource-intensive testing.
Implementation Method 1
Relative permeability can be a ratio of the effective permeability of a particular fluid at a particular saturation against the absolute permeability of the same fluid at total saturation. Effective permeability of a subsurface formation can be a measure of the ability of that particular fluid to flow in the presence of other fluid phases.
Implementation Method 2
Saturation may be the relative amount of water, carbon dioxide, and hydrocarbon in the pores of the subsurface formation.
Data Source
AI summary
A fluid injection process for injecting fluid into a wellbore can be adjusted based on relative permeability. An actual trapped gas saturation of a formation can be determined from a maximum gas saturation, a maximum trapped gas saturation, and an actual gas saturation. A pseudo-maximum gas saturation can be determined from the actual trapped gas saturation, the maximum trapped gas saturation, and actual gas saturation. A relative permeability of the formation can be determined by mapping the pseudo-maximum gas saturation along a drainage curve. The fluid injection process can be adjusted based on the relative permeability.