Drill Cutting Depth Determination Using Hydrodynamic Transport Models
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
Current methods for determining the depth of origin of drill cuttings from wellbore drilling operations are prone to measurement errors and are costly, as they do not accurately account for the transport properties of drill cuttings, particularly larger cuttings which experience significant slippage and hydrodynamic dispersion in the drilling fluid.
Innovation Solution
A method involving the extraction and characterization of drill cuttings, where smaller cuttings are used to estimate the depth of origin by accounting for hydrodynamic transport effects such as diffusion and dispersion, and larger cuttings are correlated with these estimates using a transport model, allowing for more accurate ascription of depths of provenance.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If simple calculations based on drill bit depth and fluid velocity are used to determine cutting depth, then the process is simple and fast, but measurement precision deteriorates due to unaccounted transport properties
Solution Approach 1:
The patent changes the parameters used for depth determination from simple velocity-time calculations to a comprehensive model that accounts for cutting size, density, shape, and hydrodynamic dispersion coefficients. By incorporating multiple physical parameters and their variations, the system achieves both accuracy and operational speed.
Solution Approach 2:
The patent replaces mechanical measurement methods (physical tracking of cutting transport) with a computational model that uses mathematical equations to predict cutting travel time. This substitution allows for rapid calculations while accounting for complex hydrodynamic effects that would be difficult to measure directly.
2Measurement precision
If MWD gamma ray logging and gamma ray correlation methods are used to determine depth of provenance, then measurement precision improves, but device complexity and cost increase
Solution Approach 1:
The patent uses drill cuttings themselves as intermediaries to carry formation information to the surface. Instead of using complex downhole logging tools, the cuttings act as natural carriers of formation composition data, which can then be analyzed using simpler surface-based spectroscopic or chemical methods.
Solution Approach 2:
The patent creates a computational model that replicates the complex hydrodynamic transport processes. This virtual model serves as a copy of the physical transport system, allowing accurate depth determination without needing physical measurement devices in the wellbore.
3Loss of information
If larger cuttings are transported in drilling fluid, then information about formation geometry (porosity, permeability) is preserved, but transport reliability deteriorates due to slippage and hydrodynamic dispersion
Solution Approach 1:
The patent segments the cutting population by size, density, and shape characteristics. By analyzing different cutting segments separately and applying appropriate transport models to each group, the system can accurately track larger cuttings that carry formation geometry information while accounting for their specific hydrodynamic behavior.
Solution Approach 2:
The patent implements a dynamic transport model that adapts to varying cutting properties and flow conditions. The model continuously adjusts transport predictions based on real-time parameters such as fluid velocity, cutting size distribution, and hydrodynamic dispersion coefficients, maintaining reliability despite the challenging transport of large cuttings.
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 more accurate estimations of drill cutting depths of origin, enabling better characterization of geological formations and improving hydrocarbon productivity by identifying favorable zones for hydraulic fracturing.
Implementation Method 1
The drill cuttings are carried to the surface by a drilling fluid (also known as mud or drilling mud) circulating up from the drill bit
Implementation Method 2
accounting for the transport properties of drill cuttings, particularly larger cuttings which experience significant slippage and hydrodynamic dispersion in the drilling fluid
Implementation Method 3
estimating a distribution of formation attribute characterization versus depth of provenance including solving a set of equations which define a hydrodynamic transport within the drilling fluid of the drill cuttings characterized at step c), for example the effect of diffusion and dispersion on the hydrodynamic transport
Data Source
AI summary
Techniques for determining depths of provenance of drill cuttings contained in a drilling fluid received from a wellbore. The drilling fluid contains drill cuttings of different sizes that arrive at surface at different times, and the drill cuttings originate from different formation layers at different depths along the wellbore. Such techniques may include extracting samples of drill cuttings from the drilling fluid and repeating this step as necessary to provide samples of drill cuttings that arrive at surface at different recorded times; characterizing one or more formation attributes associated with the drill cuttings; and for each formation attribute, estimating a distribution of formation attribute characterization versus depth of provenance.