Wellbore Coating Testing With Proxy Fluid Concentration Change
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Solution Overview
Problem
Existing coatings for downhole tools in oil and gas operations are difficult to inspect for uniformity and effectiveness, and testing with corrosive fluids poses health, safety, and environmental risks, making it challenging to ensure protection against corrosive fluids like hydrogen sulfide and mercury.
Innovation Solution
A proxy fluid is used to simulate corrosive fluids, allowing for a safe and effective test of coating effectiveness by measuring the change in proxy fluid concentration over time within a containment area on the coated wellbore equipment.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If corrosive fluids are used to test coating effectiveness, then measurement precision is improved, but health, safety, and environmental risks increase
Solution Approach 1:
The patent introduces a proxy fluid as an intermediary substance that simulates the properties of corrosive fluids (hydrogen sulfide, mercury, or acids) without presenting their harmful effects. The proxy fluid allows testing of coating effectiveness while eliminating health, safety, and environmental risks associated with using actual corrosive fluids.
Solution Approach 2:
The patent creates a copy or simulation of the corrosive fluid testing process using a proxy fluid that replicates the essential properties needed for coating effectiveness measurement. This copying approach enables accurate testing without requiring the actual harmful substances.
2Ease of operation
If visual inspection methods are used to check coating uniformity, then ease of operation is improved, but measurement precision deteriorates due to inability to detect non-uniformities
Solution Approach 1:
The patent replaces visual inspection (mechanical/optical observation) with a chemical testing method using proxy fluid. The proxy fluid interacts with the coating to reveal non-uniformities through concentration changes that can be measured, substituting direct visual inspection with a more precise chemical detection approach.
Solution Approach 2:
The patent utilizes color changes or concentration variations of the proxy fluid as an indicator of coating effectiveness. By introducing the proxy fluid and observing its distribution or concentration changes, non-uniformities in the coating become detectable through visual means, thus combining ease of operation with improved measurement precision.
3Reliability
If coatings are applied to protect against corrosive fluids, then reliability is improved, but difficulty of detecting and measuring coating effectiveness increases
Solution Approach 1:
The patent uses a proxy fluid as an intermediary to detect and measure coating effectiveness. The proxy fluid serves as a measurable indicator that interacts with the coating in a way that reveals its protective properties, making the previously undetectable coating effectiveness quantifiable and assessable.
Solution Approach 2:
The patent establishes a feedback mechanism by measuring the concentration or distribution of the proxy fluid after exposure to the coating. This measurement provides feedback on whether the coating is effective, allowing for assessment and verification of the protective function.
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
The method ensures the coating's effectiveness in preventing fluid absorption without exposing personnel to hazardous substances, providing accurate protection and ensuring reliable reservoir fluid analysis.
Implementation Method 1
measuring the change in proxy fluid concentration over time within a containment area on the coated wellbore equipment
Data Source
AI summary
Wellbore equipment used in oil and gas operations can be negatively affected by corrosive fluids. Coatings can be applied to the equipment to help protect the equipment. A field test can be used at a wellsite to ensure the coating is effective. Due to the HSE risks of the corrosive fluids, a proxy fluid can be used instead. The proxy fluid can have similar chemical or physical properties and simulate the corrosive fluid that is anticipated to be present in the wellbore. The wellbore equipment that is coated can be sealed to create a containment area where an initial concentration of the proxy fluid is introduced into the containment area for a period of time. A final concentration of the proxy fluid can be measured after the period of time has elapsed. By calculating the percent change of the proxy fluid, the effectiveness of the coating can be determined.