Hydrocarbon Recovery Agent Selection via Physical Core Plug Modeling
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Solution Overview
Problem
Current methods for selecting chemicals in hydraulic fracturing fluids lack effective simulation of hydrocarbon recovery processes, particularly in replicating the stages of pressure gradient and fluid flow between the formation matrix and the wellbore, which affects the efficiency of hydrocarbon extraction.
Innovation Solution
A physical modeling method using a reservoir core plug saturated with hydrocarbon and brine, combined with a multiple proppant concentration method, to simulate the three stages of hydraulic fracturing, including fracturing, shut-in, and production, and evaluate the efficacy of hydrocarbon recovery agents by displacing fluids and conducting imbibition tests, while visualizing fluid saturation and determining permeability.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If traditional chemical selection methods are used for hydraulic fracturing fluids, then the selection process is simple, but the accuracy of evaluating hydrocarbon recovery efficiency is insufficient
Solution Approach 1:
The patent creates a physical model that copies the actual hydrocarbon reservoir system, including core plugs saturated with hydrocarbon and brine, to simulate real reservoir conditions. This model allows accurate evaluation of hydrocarbon recovery efficiency while maintaining manageable complexity through controlled laboratory-scale replication of field conditions.
Solution Approach 2:
The patent introduces a fracturing fluid as an intermediary substance that mediates between the injection system and the hydrocarbon-saturated core plug. This intermediary allows systematic evaluation of different chemical formulations and their effects on hydrocarbon displacement and recovery without directly modifying the core plug or reservoir.
2Reliability
If a physical modeling method with multiple proppant concentrations is used, then the simulation of hydraulic fracturing stages is improved, but the time required for evaluation increases
Solution Approach 1:
The patent segments the hydraulic fracturing process into distinct stages (fracturing, shut-in, and production) and evaluates each stage separately using controlled core flooding experiments. This segmentation allows comprehensive simulation of all fracturing stages while managing evaluation time by focusing on one stage at a time with optimized experimental protocols.
Solution Approach 2:
The patent systematically changes key parameters such as proppant concentration (0, low, intermediate, high) and fracturing fluid composition to simulate different hydraulic fracturing scenarios. By controlling and varying these parameters methodically, the patent achieves reliable simulation of multiple fracturing stages while reducing unnecessary evaluation time through targeted parameter studies.
3Loss of information
If core flooding experiments with multiple proppant concentrations are conducted, then the understanding of fluid flow dynamics is enhanced, but the complexity of experimental setup increases
Solution Approach 1:
The patent employs a universal core flooding apparatus that can handle multiple proppant concentrations and different fracturing fluid formulations within a single experimental setup. This multi-functional device reduces overall experimental complexity by eliminating the need for separate specialized apparatus for each proppant concentration level, while still capturing comprehensive fluid flow dynamics information.
Solution Approach 2:
The patent uses simplified core plug models that copy the essential features of actual reservoir rock (porosity, permeability, saturation) without requiring full-scale reservoir replication. This copying approach preserves critical fluid flow dynamics information while significantly reducing experimental apparatus complexity compared to full-scale field testing.
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 allows for the precise evaluation and optimization of hydrocarbon recovery agents by replicating the multiphase fluid flow and pressure gradients, enhancing the effective permeability and recovery efficiency of hydrocarbons.
Implementation Method 1
pumping the fracturing fluid through saturated core plug to displace a portion of the hydrocarbon to form a displaced hydrocarbon plug
Implementation Method 2
positioning the displaced hydrocarbon plug in an imbibition cell and conducting an imbibition test to form an imbibed core plug having brine and hydrocarbon
Implementation Method 3
positioning the imbibed core plug in core-flooding apparatus and displacing a portion of the brine and hydrocarbon from the imbibed core plug
Data Source
AI summary
A physical modeling method that includes providing a reservoir core plug, the reservoir core plug having a wellbore interface end, an outlet interface end, and a cylindrical face and saturating the reservoir core plug with hydrocarbon and brine to form a saturated core plug. The method also includes positioning the saturated core plug within a flooding apparatus and pumping the fracturing fluid through saturated core plug to displace a portion of the hydrocarbon to form a displaced hydrocarbon plug. In addition the method includes positioning the displaced hydrocarbon plug in an imbibition cell and conducting an imbibition test to form an imbibed core plug having brine and hydrocarbon. Further the method includes positioning the imbibed core plug in core-flooding apparatus and displacing a portion of the brine and hydrocarbon from the imbibed core plug.