Fracturing Fluid Viscosity Control via Chelation and Produced Water
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Solution Overview
Problem
Current hydraulic fracturing fluids face challenges in maintaining viscosity and stability at high temperatures and pressures, which affects fracture initiation, propagation, and hydrocarbon extraction efficiency.
Innovation Solution
A fracturing fluid composition comprising a chelating agent, such as tetrasodium glutamate diacetate, a polymeric gelling agent like carboxymethyl hydroxypropyl guar gum, and a base fluid with high total dissolved solids content, specifically designed to maintain viscosity at high temperatures and pressures, and then reduce viscosity for efficient hydrocarbon extraction.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Strength
If hydraulic fracturing fluids are used to create fractures in hydrocarbon formations, then fracture initiation and propagation are achieved, but the fluid viscosity becomes too high for efficient hydrocarbon extraction
Solution Approach 1:
The fracturing fluid is designed to dynamically change its viscosity based on conditions. At high temperatures and pressures during fracture creation, the fluid maintains high viscosity to create effective fractures. After fracture creation, the fluid viscosity decreases to enable efficient hydrocarbon extraction, thus adapting to different operational stages
Solution Approach 2:
The fluid composition utilizes temperature and pressure changes to alter its physical properties. The high temperature and pressure conditions during fracture injection naturally reduce fluid viscosity, enabling the fluid to transition from a high-viscosity fracture-creation state to a low-viscosity extraction state
2Shape
If complex chemical mixtures are included in hydraulic fracturing fluids to generate fracture geometry, then fracture propagation is improved, but the fluid stability deteriorates at high temperatures and pressures
Solution Approach 1:
The patent utilizes temperature and pressure parameter changes to control fluid behavior. The high temperature and pressure conditions during fracture injection naturally reduce fluid viscosity and maintain stability, allowing the fluid to achieve effective fracture geometry without requiring complex stabilizing chemical mixtures
3Stability of the object's composition
If produced fluid with high total dissolved solids is used as base fluid, then viscosity maintenance at high temperatures is improved, but the fluid compatibility with formation rock deteriorates
Solution Approach 1:
The patent converts the high total dissolved solids content, which is typically considered a harmful factor affecting formation rock interaction, into a beneficial property. The high dissolved solids content naturally maintains fluid viscosity at high temperatures, eliminating the need for additional viscosity maintenance additives and improving overall fluid stability during fracture creation
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 effectively maintains high viscosity for fracture creation and then decreases viscosity for efficient hydrocarbon extraction, enhancing the conductivity of fractures and improving hydrocarbon recovery.
Implementation Method 1
The fracturing fluid may contain a chelating agent, such as tetrasodium glutamate diacetate
Implementation Method 2
a polymeric gelling agent like carboxymethyl hydroxypropyl guar gum
Implementation Method 3
The fracturing fluid may have a viscosity of at least 200 cp at 150° F., 100 1/s shear rate, and 300 psia
Implementation Method 4
The base fluid may be a produced fluid that has a hardness content of at least 7,000 ppm... effectively maintains high viscosity for fracture creation
Implementation Method 5
The fracturing fluid may have a viscosity of at least 200 cp at 150° F., 100 1/s shear rate... After contacting the hydrocarbon-bearing formation, the viscosity of the fracturing fluid may drop near a range of 1 cP to 5 cP
Data Source
AI summary
A composition for a fracturing fluid may include a chelating agent, a polymeric gelling agent, and a base fluid. The base fluid in the fracturing fluid composition may be a produced fluid having a hardness content of at least 7,000 ppm. Method for treating a hydrocarbon-bearing formation may include introducing a fracturing fluid in the hydrocarbon-bearing formation. The fracturing fluid contains a chelating agent, a polymeric gelling agent, and a base fluid. The base fluid may be a produced fluid that has a hardness content of at least 7,000 ppm. The fracturing fluid may have a viscosity of at least 200 cp at 150° F., 100 1/s shear rate, and 300 psia when tested using model 5550 HPHT rheometer. After contacting the hydrocarbon-bearing formation, the viscosity of the fracturing fluid may drop near a range of 1 cP to 5 cP.