Fracturing Fluid Optimization via Rock Characterization
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Solution Overview
Problem
Current methods for optimizing fracturing fluids in hydraulic fracturing are inefficient, requiring a trial-and-error approach due to the need for specific fluid compositions that match the unique properties of each shale play, leading to significant time and cost expenditures, and often result in reduced permeability and clogging issues.
Innovation Solution
A systematic method involving comprehensive data collection and analysis to characterize rock, brine, and hydrocarbon samples, followed by synthesizing fracturing fluid compositions based on specific criteria such as rock-fluid interactions, ion selectivity, and imbibition properties, to optimize fluid performance and compatibility.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Reliability
If a trial-and-error approach is used to optimize fracturing fluid compositions, then fluid compatibility with reservoir rock and fluids can be achieved, but significant time and cost are consumed
Solution Approach 1:
The patent performs preliminary characterization of reservoir rock, brine, and hydrocarbon properties before fluid synthesis. Rock parameters include mineralogy, pore structure, and surface properties; brine parameters include composition and properties; hydrocarbon parameters include composition and properties. This preliminary data collection enables predictive modeling to determine optimal fracturing fluid compositions before actual field application, eliminating trial-and-error time consumption.
Solution Approach 2:
The patent systematically varies multiple fluid parameters including composition, concentration, temperature, and pressure to optimize performance. The method evaluates different cation types and concentrations, additive combinations, and fluid properties to identify optimal parameters that maximize fracture effectiveness while minimizing time and cost.
2Stability of the object's composition
If aggregating fracture fluids are used to stabilize the fracture zone, then clay particles are bound together, but the pay zone becomes clogged and occluded with clay particles
Solution Approach 1:
The patent applies different fluid chemistries to different zones within the formation. Dispersing fracture fluids are used in zones with clay particles to prevent clogging, while aggregating fracture fluids are used in zones requiring stability without clay presence. The method selectively applies fluid types based on local rock composition and pay zone characteristics to achieve stability without clogging.
Solution Approach 2:
The patent converts the potentially harmful effect of clay particles into a beneficial one by using dispersing fracture fluids that specifically target and disperse clay particles, preventing them from clogging the pay zone. The method transforms the clay particle problem into an opportunity to enhance fracture zone stability through selective fluid application.
3Productivity
If fracturing fluids are used to create fractures in tight shale formations, then hydrocarbon production is enhanced, but fluid losses occur and permeability is reduced
Solution Approach 1:
The patent incorporates feedback mechanisms through laboratory testing and modeling to predict and adjust fluid loss. Rock core analyses and core flood tests provide feedback on fluid interaction with the formation, enabling optimization of fluid composition and properties to minimize fluid loss while maintaining permeability and enhancing production.
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 enables the selection of optimal fracturing fluids that enhance fracture effectiveness, reduce fluid loss, and maintain long-term well performance by improving fluid compatibility and permeability, thereby increasing hydrocarbon recovery efficiency.
Implementation Method 1
injecting a fluid into the wellbore at a sufficient rate and pressure to part or open existing fractures and/or overcome the tensile strength of the formation
Implementation Method 2
have sufficient viscosity and structure to suspend proppants if present, and transport them deep into the formation
Implementation Method 3
A dispersing fracture solution in the fracture zone will disperse clays and other earthen particles and allow them to be carried by the flow-back fluids out of the hydrocarbon producing fracture zone
Implementation Method 4
An aggregating fracture solution will aggregate and bind clays and other earthen materials. This stabilizes the fracture zone
Implementation Method 5
There is also a need for improved methods and systems to optimize fracturing fluid chemistry taking into consideration of factors including but not limited to imbibition, diffusion and interrelations between the fracturing fluid and reservoir rock
Implementation Method 6
The test comprises an interfacial tension test to determine contact angle, zeta potential, wettability, interfacial tension properties
Data Source
AI summary
A workflow to optimize a fracturing fluid for injection into a subterranean formation is provided. The workflow comprises measurement of fundamental properties and characteristics of reservoir rock and fluid, their interaction with fracturing fluid, computer-based models and laboratory performance testing to select preferred fracturing base fluid and additives package for use in fracturing/re-fracturing stimulation of specific shale formations to enhance hydrocarbon recovery.