Synthetic Copolymer Fracturing Fluid High Temperature Stability
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Solution Overview
Problem
Guar-based fracturing fluids lose viscosity and effectiveness at high temperatures, leading to inadequate proppant placement and fracture geometry control in deep, hot subterranean formations, necessitating a stable and controlled degradation fracturing fluid.
Innovation Solution
A high temperature well treatment fluid comprising water, a high molecular weight synthetic copolymer derived from acrylamide, acrylamidomethylpropanesulfonic acid, and vinyl phosphonate, along with a pH buffer to maintain a pH range of 4.5 to 5.25, and optional additives like crosslinking agents, stabilizers, and breakers for enhanced stability and controlled degradation.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Temperature
If guar-based fracturing fluids are used at high temperatures, then the fluid can be injected into deep formations, but the fluid loses viscosity and effectiveness
Solution Approach 1:
The patent changes the chemical composition parameters by replacing guar-based polymers with synthetic copolymers having specific monomer ratios (acrylamide, acrylamidomethylpropanesulfonic acid, vinyl phosphonate) that are thermally stable up to 500°F, thereby maintaining viscosity at high temperatures while enabling deep formation treatment
Solution Approach 2:
The invention uses composite fracturing fluids combining synthetic copolymers with crosslinking agents and stabilizers to create a multi-component system that maintains structural integrity and viscosity at elevated temperatures, overcoming the limitations of single-component guar-based fluids
2Productivity
If guar-based polymers are used for proppant transport, then the fluid can be pumped at high rates, but the polymer degrades too quickly
Solution Approach 1:
The patent modifies the polymer degradation parameters by introducing crosslinking agents that form thermally stable crosslinked networks, extending the effective service life of the fracturing fluid from minutes to hours at high temperatures, thereby ensuring complete proppant placement before degradation
3Stability of the object's composition
If the fracturing fluid is stabilized to travel further distances, then the fluid can reach deeper fractures, but the fluid becomes difficult to clean out
Solution Approach 1:
The invention introduces controlled degradation mechanisms through specific crosslinking agents and breakers that allow the fluid to transition from a stable, high-viscosity state during fracturing to a degraded, low-viscosity state for easy removal, enabling the fluid to perform its function and then be easily cleaned out
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 fluid maintains viscosity and stability at temperatures up to 500°F (260°C) for extended periods, enabling effective fracturing and easy cleanup, outperforming traditional guar-based fluids in deep and hot formations.
Implementation Method 1
The pH buffer enables the high temperature well treatment fluid to maintain a pH in a range of about 4.5 to about 5.25
Implementation Method 2
The high temperature well treatment fluid includes water, a high molecular weight synthetic copolymer... capable of fracturing a subterranean formation in temperatures of up to about 500° F. (260° C.)
Data Source
AI summary
Compositions and methods of treating high temperature subterranean formations of up to about 500° F. (260° C.) are provided. The compositions and methods utilize a high molecular weight synthetic copolymer and a pH buffer than maintains a pH in a range of about 4.5 to about 5.25 for the compositions. The high molecular weight synthetic copolymer is derived from acrylamide, acrylamidomethylpropanesulfonic acid, and vinyl phosphonate.