Well Transmissivity Measurement via Multi-Log Integration
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Solution Overview
Problem
Current methods for determining fluid flow profiles in subsurface hydrocarbon reservoirs are expensive, time-consuming, and often rely on subjective estimates, especially for horizontal wells, as they require production logging tool runs which are not feasible for all wells, leading to incomplete analysis of formation flow.
Innovation Solution
A method and system that utilize data from logging while drilling, permeability, and viscosity logging tools to process measures of formation thickness, permeability, and fluid viscosity to determine fluid transmissibility, enabling the creation of accurate flow profiles without the need for extensive production logging tool runs, by using a computer system to integrate data from these tools and account for relative permeability.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If production logging tool runs are used to determine flow profiles, then measurement precision is improved, but cost and time consumption increase significantly
Solution Approach 1:
The patent creates a computational model that replicates the functionality of production logging tools by integrating data from multiple existing logging tools (resistivity, NMR, acoustic, etc.) to generate flow profile information without requiring actual production logging tool runs. This virtual copy approach maintains measurement precision while eliminating time consumption.
Solution Approach 2:
The patent introduces a computer-based processing system that acts as an intermediary, taking data from various logging tools and transforming it into flow profile information through mathematical models and algorithms. This intermediary processing eliminates the need for direct production logging tool runs while preserving measurement accuracy.
2Reliability
If production logging tool runs are used to evaluate all wells, then reliability of flow profile data is improved, but device complexity and operational difficulty increase
Solution Approach 1:
The patent creates a universal processing system that can evaluate multiple wells using data from standard logging tools already in use. The system performs multiple functions: integrating data from different tool types, applying appropriate mathematical models, and generating flow profile information for various well conditions without requiring specialized production logging tool runs for each well.
Solution Approach 2:
The patent enables the existing logging data and standard processing systems to serve themselves by automatically integrating and analyzing data from multiple sources to produce flow profile information. This self-service approach eliminates the need for additional specialized tool runs and manual evaluation processes.
3Ease of operation
If subjective estimates and intuition are used for well selection, then ease of operation is maintained, but measurement precision and reliability of flow profile analysis deteriorate
Solution Approach 1:
The patent implements a feedback-based selection process where the computer system automatically evaluates wells based on the quality and completeness of available logging data, applying mathematical models to predict flow profiles. This feedback loop replaces subjective judgment with objective, data-driven criteria while maintaining ease of operation through automated processing.
Solution Approach 2:
The patent replaces the mechanical process of subjective human evaluation with an automated computer-based system that uses mathematical models and algorithms to assess wells and generate flow profile information. This substitution eliminates subjectivity while maintaining operational simplicity through automated decision-making.
Data Source
AI summary
Models of fluid flow in wells in formation of a subsurface earth reservoir are formed by computers based on measurements obtained by well logging tools run in the wells and measurements of formation rock characteristics obtained from laboratory data. The models so formed are used to form measures of injection/production profiles and assist reservoir engineers in allocation of production and injection wells for the reservoir, and in other reservoir production planning and analysis.