Borehole Fluid Analysis for Mud Contamination Correction
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Solution Overview
Problem
Existing methods for characterizing petroleum fluid properties are hindered by contamination from drilling mud, leading to inaccurate measurements and computational delays, especially in real-time analysis and for high GOR systems.
Innovation Solution
A system and methodology that characterizes petroleum fluid properties in real-time by processing data to account for mud filtrate contamination, including measurements of viscosity and density at formation conditions, and accounts for excess volume created during mixing processes, using a borehole tool with a fluid analysis module that measures temperature, pressure, and optical properties to derive accurate properties unaffected by mud contamination.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional borehole sampling and analysis tools are used to measure petroleum fluid properties, then fluid characterization data can be obtained, but the measurements are inaccurate due to contamination from drilling mud filtrate
Solution Approach 1:
The patent extracts and removes the harmful mud filtrate contamination from the fluid sample by separating the contaminated petroleum fluid into clean petroleum fluid and mud filtrate components, thereby eliminating the source of measurement error
Solution Approach 2:
The patent introduces an intermediary cleaning process between sampling and analysis that uses centrifugal separation to remove mud filtrate, acting as a mediator that protects the measurement system from contamination while preserving the integrity of the petroleum fluid sample
2Measurement precision
If cleaning processes are applied to remove mud filtrate contamination, then measurement accuracy improves, but computational time and processing delays increase
Solution Approach 1:
The patent performs preliminary cleaning of the fluid sample at the borehole location before analysis, removing mud filtrate contamination in advance so that subsequent measurements can be performed quickly without extensive computational correction processes
Solution Approach 2:
The patent replaces complex computational algorithms with a mechanical centrifugal separation system that physically removes contamination, substituting mechanical action for computational processing to reduce time delays
3Measurement precision
If standard mixing rules are used to account for mud contamination, then some correction can be applied, but accuracy is insufficient for high GOR systems due to excess volume effects
Solution Approach 1:
The patent changes the approach from using standard mixing rules to applying excess volume correction factors that account for the non-ideal behavior of high GOR systems, adjusting the parameters used in calculations to match the specific characteristics of gas-rich petroleum fluids
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
Enables accurate, real-time characterization of petroleum fluid properties, improving measurement accuracy for contaminated samples and reducing computational delays, particularly for high GOR systems by compensating for mud contamination and excess volume effects.
Implementation Method 1
the fluid analysis module measures absorption spectra and translates such measurements into concentrations
Implementation Method 2
measurements of viscosity and density at formation conditions
Implementation Method 3
measurements of viscosity and density at formation conditions
Data Source
AI summary
A method and system for characterizing formation fluids contaminated with drilling mud that compensates for the presence of such drilling mud. The operations that characterize formation fluids contaminated with drilling mud can be carried out in real-time. The operations also characterize a wide array of fluid properties of petroleum samples contaminated with drilling mud in a manner that compensates for the presence of drilling mud. The operations characterize the viscosity and density of petroleum samples contaminated with drilling mud at formation conditions in a manner that compensates for differences between formation conditions and flowline measurement conditions. The operations also derive live fluid density unaffected by contamination of mud filtrate based on a scaling coefficient dependent on measured gas-oil ratio of the formation fluid. This scale factor accounts for excess volume created during mixing processes, which increases the accuracy of characterizations for high gas-oil ratio samples, especially gas condensate.