Non-magnetic solid tracers for wellbore flow mapping
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Solution Overview
Problem
Current methods for assessing unconventional reservoirs and optimizing multi-stage hydraulic fracturing are costly, environmentally challenging, and lack the accuracy and speed needed for effective decision-making.
Innovation Solution
The use of ultrahigh resolution nanoparticle tracers injected into wellbores during hydraulic fracturing, which allow for real-time flow mapping and completion optimization by analyzing remnant fluids using advanced spectroscopy techniques.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If fiber optic systems with distributed acoustic sensing and distributed temperature surveys are used, then high-end diagnostic results are provided, but cost and deployment complexity increase excessively
Solution Approach 1:
The patent extracts the sensing function from complex fiber optic systems and implements it using simple, inexpensive tracer chemicals that can be easily injected and recovered. The tracer molecules themselves serve as the sensing element, eliminating the need for complex fiber optic deployment infrastructure while maintaining diagnostic capability.
Solution Approach 2:
The patent uses inexpensive tracer chemicals that can be easily injected into the formation and recovered from produced fluids. These tracers are disposable in the sense that they are injected for a specific diagnostic purpose and then discarded with the produced fluids, eliminating the need for expensive, reusable fiber optic systems that require complex installation and maintenance.
2Loss of information
If conventional liquid chemical tracers are used, then flow mapping capability is provided, but tracer formulation complexity increases due to solubility requirements
Solution Approach 1:
The patent changes the physical state parameter of the tracer from liquid to solid particulate form. This fundamental parameter change eliminates solubility constraints, allowing the use of diverse solid materials with varying densities, magnetic properties, and fluorescent characteristics without requiring complex solvent systems or formulation adjustments for different well conditions.
3Reliability
If multiple tracer formulations are used for different fluid types, then tracer effectiveness is maintained, but cost increases appreciably
Solution Approach 1:
The patent develops universal solid tracer formulations that can be used across all fluid types (oil, water, gas) without requiring separate formulations. The solid particulate tracers are inert and can be carried by any fluid phase, eliminating the need for multiple specialized tracer products and reducing overall tracer program costs while maintaining effectiveness across different well conditions.
4Loss of information
If conventional tracer testing with offsite laboratory analysis is used, then comprehensive interpretation is provided, but time required increases to three weeks or more
Solution Approach 1:
The patent replaces the mechanical/chemical analysis system (offsite laboratory procedures requiring sample preparation, dissolution, and specialized instrumentation) with optical detection methods. Fluorescent tracers can be detected directly in produced fluids using portable or inline fluorescence detectors, eliminating the need for complex laboratory analysis while providing rapid results within hours rather than weeks.
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 provides accurate, timely, and cost-effective data on wellbore performance and fracturing efficiency, reducing environmental impact and improving well economics.
Implementation Method 1
The testing the sample step may include using a fluorescence response-based analysis
Data Source
AI summary
A method of using a tracer additive in a wellbore that includes forming a utility fluid mixture comprising the tracer additive, and disposing the utility fluid into the wellbore so that the utility fluid comes into contact with a target formation. Upon contacting the utility fluid with the target formation for an amount of time, returning a remnant fluid that includes at least a portion of the utility fluid to a surface for testing. The tracer additive has a first composition, and is in a solid non-magnetic powder.