Labile Synthetic Polymer Fracturing Fluid
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Solution Overview
Problem
Guar-based fracturing fluids face limitations due to supply constraints, hydration issues, formation damage, and instability at elevated temperatures, making it economically and technically challenging to achieve high viscosity for effective hydraulic fracturing.
Innovation Solution
A synthetic polymer-based fracturing fluid with a labile group that decomposes upon activation, combined with an oxidizing agent, to achieve controlled viscosity reduction and equipment protection, facilitating efficient hydraulic fracturing.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Strength
If guar polymer concentration is increased to achieve high viscosity, then the fracturing fluid can carry more proppants and create wider fractures, but the cost increases significantly and formation damage occurs
Solution Approach 1:
The patent changes the chemical structure parameters of the polymer by introducing labile groups (such as acetal, orthoester, or carbonate groups) into the polymer backbone. These structural modifications enable the polymer to decompose under specific downhole conditions (temperature, pH), transforming the fluid from high viscosity during pumping to low viscosity during production, thereby reducing formation damage and operational costs while maintaining effective proppant transport capability
Solution Approach 2:
The fracturing fluid viscosity is made dynamic and adjustable through the inclusion of labile groups that respond to downhole environmental changes. The polymer maintains high viscosity during surface pumping to effectively transport proppants, then automatically decomposes at downhole temperatures and pH conditions to reduce viscosity for easy fluid recovery and minimal formation damage, eliminating the need for expensive crosslinking agents and breakers
2Strength
If guar-based fracturing fluids are used, then viscosity can be achieved for effective proppant transport, but supply limitations and hydration issues arise
Solution Approach 1:
The patent employs a synthetic polymer with labile groups that is designed to be consumed or decomposed after serving its primary function. The polymer provides necessary viscosity during the fracturing operation, then decomposes under downhole conditions to allow fluid recovery and minimize formation damage. This disposable approach eliminates supply limitations associated with natural guar and avoids long-term formation damage from residual polymers
Solution Approach 2:
The patent creates a composite polymer structure combining a backbone chain with labile functional groups (acetal, orthoester, or carbonate groups). This composite structure integrates the viscosity-providing capability of polymer chains with the controlled decomposition feature of labile groups, achieving both effective proppant transport during pumping and easy fluid recovery during production without relying on natural guar supply
3Strength
If crosslinked guar polymers are used to maintain high viscosity at elevated temperatures, then proppant transport capability is improved, but the fluid requires breakers for recovery and may cause formation damage
Solution Approach 1:
The patent enables the fracturing fluid to self-decompose through the inherent instability of labile groups (acetal, orthoester, or carbonate groups) at downhole temperatures and pH conditions. The polymer automatically breaks down without requiring external breaker chemicals or complex recovery systems, simplifying the overall process while maintaining high viscosity during pumping and enabling easy fluid recovery during production
Solution Approach 2:
Instead of using stable crosslinked polymers that require chemical breakers for decomposition, the patent inverts the approach by using inherently unstable polymers with labile groups that spontaneously decompose under downhole conditions. This inversion eliminates the need for complex breaker systems and reduces formation damage from residual crosslinked polymers, while maintaining effective viscosity during the fracturing operation
4Productivity
If high pumping rates are used to transport proppants, then fracturing efficiency is improved, but equipment wear increases due to abrasive proppants
Solution Approach 1:
The patent uses a polymer fluid with labile groups as an intermediary medium that provides high viscosity during pumping to effectively suspend and transport abrasive proppants at high rates. The polymer acts as a protective intermediary between the proppants and equipment, reducing direct contact and wear. After the fracturing operation, the polymer decomposes under downhole conditions, allowing easy fluid recovery and eliminating residual damage to formation and equipment
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 synthetic polymer fluid rapidly dissolves to reduce equipment friction, maintains high viscosity for effective proppant transport, and decomposes easily for fluid recovery, minimizing formation damage and operational costs.
Implementation Method 1
The polymer being crosslinked, the fracturing fluid having a viscosity of about 200 to about 3000 centipoise at 100 s−1
Implementation Method 2
the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group
Implementation Method 3
the fracturing fluid comprising an oxidizing agent
Data Source
AI summary
Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; the polymer being crosslinked, the fracturing fluid having a viscosity of about 200 to about 3000 centipoise at 100 s−1; and an oxidizing agent. A method for treating a hydrocarbon-bearing formation is also disclosed herein.