Fracturing Pumping Rate Calculation for Proppant Placement
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Solution Overview
Problem
Existing methods fail to accurately determine the appropriate pumping rate for proppant placement during hydraulic fracturing, leading to ineffective or unstable fractures in low- or ultra-low-permeability formations.
Innovation Solution
A method and device for determining pumping rate that involves acquiring specific proppant mesh size, bulk density, carrier fluid viscosity, and fracture geometry to calculate an optimal pumping rate using pre-established models, adjusting mesh size if necessary to ensure the rate falls within a preset limit.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If an excessively high pumping rate is used, then the fracturing process can be completed faster, but the fracture becomes inoperative and proppant placement efficiency deteriorates
Solution Approach 1:
The patent applies parameter changes by establishing a pumping rate calculation model that dynamically determines the optimal pumping rate based on multiple parameters including proppant bulk density, carrier fluid density, carrier fluid viscosity, distance from wellbore to fracture tip, average fracture width, and sand ratio. This ensures the pumping rate is optimized for each specific fracturing scenario, preventing both excessive and insufficient rates that would compromise fracture functionality or productivity
2Loss of energy
If an insufficient pumping rate is used, then the fracturing process consumes less energy, but effective fractures cannot be created and productivity is compromised
Solution Approach 1:
The patent uses parameter changes to determine the minimum effective pumping rate by incorporating proppant bulk density, carrier fluid viscosity, fracture geometry, and sand ratio into the calculation model. This ensures sufficient pumping rate to create effective fractures while avoiding excessive energy consumption from unnecessarily high rates
3Ease of operation
If a fixed pumping rate is used for all proppant mesh sizes, then the operation is simpler, but proppant placement efficiency varies and cannot be optimized
Solution Approach 1:
The patent addresses this contradiction by creating mesh-size-specific pumping rate calculation models. Different mesh sizes (30/50, 40/70, 70/140, 100/200) have dedicated calculation models that incorporate their specific bulk density values and sand ratio coefficients. This provides optimized pumping rates for each mesh size to maximize proppant placement efficiency while maintaining relatively simple operation through standardized calculation procedures
Solution Approach 2:
The patent applies segmentation by dividing the pumping rate determination into separate calculation models for different proppant mesh sizes. Each model (Qp30/50, Qp40/70, Qp70/140, Qp100/200) is tailored to specific mesh size characteristics, allowing precise optimization for each proppant type while maintaining operational simplicity through consistent methodology
Data Source
AI summary
A method and apparatus are provided for determining the pumping rate to improve proppant placement efficiency. The method includes: acquiring proppant mesh size, bulk density, carrier fluid density and viscosity at reservoir temperature; determining the fracture length from the wellbore to the tip and average fracture width; and obtaining a preset proppant concentration. These parameters are input into a calculation model to compute the pumping rate. The method enables accurate pumping rate determination and enhances placement efficiency.