Drilling Fluid Particle Size Distribution Control for Cuttings Transport
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Solution Overview
Problem
In oil and gas drilling operations, the transport of cuttings and cavings in non-vertical wellbores is inefficient, leading to issues like drill pipe sticking, increased torque, and lower penetration rates due to complex fluid dynamics and wellbore instability, which existing methods poorly understand and fail to effectively address.
Innovation Solution
A method using a computer-based particle transport model to estimate and adjust the particle size distribution and mass rate of drilling fluid to enhance the transport of cuttings and cavings by calculating a target particle size distribution and adding specific particles to the drilling fluid, thereby improving wellbore cleaning and stability.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If drilling fluid is pumped at high flow rate to improve cuttings transport, then cuttings transport rate is improved, but energy consumption and torque increase
Solution Approach 1:
The patent changes the physical-chemical parameters of the drilling fluid by adding surfactants and polymers to modify its rheological properties. This allows the fluid to maintain effective cuttings transport at lower flow rates by improving its ability to suspend and carry cuttings through enhanced lubrication and reduced friction, thereby resolving the contradiction between transport rate and energy consumption
Solution Approach 2:
The patent creates a composite drilling fluid system by combining base drilling fluid with surfactants and polymer additives. This composite formulation enhances the fluid's overall performance in cuttings transport while allowing operation at optimized flow rates that reduce energy consumption compared to conventional single-component drilling fluids
2Productivity
If drilling fluid viscosity is increased to improve cuttings suspension, then cuttings transport is improved, but fluid flow rate and penetration rate decrease
Solution Approach 1:
The patent modifies the rheological parameters of the drilling fluid by incorporating surfactants and polymers that enhance suspension capability through improved viscoelasticity and lubrication properties. This allows the fluid to maintain cuttings suspension at lower viscosities than conventional fluids, preserving flow rate and penetration rate while improving transport efficiency
3Productivity
If drill string rotation speed is increased to improve drilling speed, then penetration rate is improved, but cuttings accumulation and torque increase
Solution Approach 1:
The patent introduces surfactants and polymers as intermediary substances that modify the interaction between cuttings and drilling fluid. These additives reduce friction and improve lubrication, allowing cuttings to be more effectively transported away from the drill bit at higher rotation speeds, thereby resolving the contradiction between penetration rate and cuttings accumulation
Solution Approach 2:
The patent changes the tribological parameters of the drilling system by adding lubricating additives to the drilling fluid. This reduces the friction coefficient between cuttings and drill string, enabling higher rotation speeds without proportionally increasing torque and cuttings accumulation, thus improving penetration rate while controlling harmful effects
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 enhances the transport rate of cuttings and cavings, reducing the likelihood of wellbore instability and pressure spikes, leading to improved drilling efficiency and reduced risk of pipe sticking and increased torque.
Implementation Method 1
The drilling fluid being pumped down the drill pipe is injected into the wellbore at the drill bit to provide a mechanism for the cuttings to be transported out of the borehole through the annulus
Implementation Method 2
The drilling fluid being pumped down the drill pipe is injected into the wellbore at the drill bit to provide a mechanism for the cuttings to be transported out of the borehole
Implementation Method 3
in horizontal or near-horizontal wells, may result in undesirable cuttings accumulations known as cuttings beds
Data Source
AI summary
Methods for enhancing transport rate of particles of size Dm in a cuttings bed within an annulus of a wellbore during drilling operations. One method comprises estimating, with a computer, a current particle size distribution (PSD) of a particle bed including particles of size Dm within a measured depth (MD) range of the wellbore; calculating, with the computer, a target PSD of the MD range using a using a one-dimensional transient model incorporating a particle transport model; determining, with the computer, a pumping PSD to achieve the target PSD within the MD range; and adding the pumping PSD to a drilling fluid flowing within the annulus, thereby enhancing the transport rate of particles of size Dm within the MD range. The particle transport model may be a surface-based transport model.