Dynamic Pumping Schedule for Well Stimulation
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Solution Overview
Problem
Well stimulation processes face challenges in dynamically optimizing pumping schedules to effectively reduce blockages in subterranean formations, as existing methods do not account for changing characteristics of layers during fluid injection, leading to inefficient fluid distribution and reduced production rates.
Innovation Solution
A computing device dynamically adjusts the pumping schedule by simulating fluid injection into a wellbore, determining the type and rate of fluids based on real-time sensor data and layer characteristics, such as permeability and leak-off rates, to optimize fluid distribution and reduce blockages below a threshold value, using a prioritized list of layers that may change as the treatment progresses.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If a fixed pumping schedule is used for acidizing treatment, then the treatment process is simple to implement, but the fluid distribution becomes inefficient and blockages are not effectively reduced
Solution Approach 1:
The patent implements dynamic pumping schedules that automatically adjust pump rates based on real-time layer characteristics and fluid distribution patterns. The system transitions from static fixed schedules to dynamic adaptive schedules that respond to changing formation conditions, thereby improving blockage reduction efficiency while managing complexity through automated control algorithms.
Solution Approach 2:
The system incorporates feedback mechanisms that monitor layer characteristics (permeability, blockage levels) and fluid distribution patterns during acidizing treatment. This feedback is used to continuously optimize pumping schedules, allowing the system to adapt to changing formation conditions and improve treatment effectiveness while maintaining manageable operational complexity through automated decision-making.
2Productivity
If high pump rates are used to create channels in carbonate formations, then channel creation is effective, but fluid distribution to other layers is reduced and overall treatment efficiency decreases
Solution Approach 1:
The patent applies local quality by assigning different pump rates to different layers based on their specific characteristics (permeability, blockage level, formation type). Instead of using a uniform high pump rate for all layers, the system tailors the pumping parameters to each layer's needs, ensuring optimal channel creation in carbonate formations while maintaining adequate fluid distribution to other layers through differentiated pumping schedules.
Solution Approach 2:
The system segments the acidizing treatment into layer-specific pumping operations. Each layer receives a customized pumping schedule based on its characteristics, allowing high pump rates to be applied locally where channel creation is needed while maintaining lower rates for other layers, thereby optimizing both channel creation effectiveness and overall fluid distribution.
3Productivity
If low pump rates are used for compact dissolution in sandstone formations, then wellbore radius increase is achieved, but treatment time increases and productivity decreases
Solution Approach 1:
The patent implements dynamic pumping schedules that adjust pump rates based on real-time monitoring of wellbore radius increase and layer characteristics. Instead of maintaining a fixed low pump rate throughout the treatment, the system dynamically optimizes the pump rate to achieve the desired wellbore radius increase in minimum time, thereby reducing treatment time while maintaining productivity.
Solution Approach 2:
The system changes pumping parameters (pump rate, fluid type, injection pressure) based on real-time treatment progress and layer characteristics. For sandstone formations undergoing compact dissolution, the system dynamically adjusts pump rates to optimize the balance between wellbore radius increase and treatment time, transitioning from static low rates to adaptive parameter changes that reduce overall treatment duration.
4Productivity
If pumping schedules are not dynamically adjusted, then operational simplicity is maintained, but fluid and time consumption increases and production rates are not maximized
Solution Approach 1:
The patent incorporates feedback mechanisms that monitor layer characteristics, fluid distribution patterns, and treatment progress in real-time. This feedback enables the system to dynamically adjust pumping schedules to optimize fluid consumption and maximize production rates, avoiding both under-treatment and over-treatment scenarios that would waste fluid and time.
Solution Approach 2:
The system dynamically changes pumping parameters (pump rate, fluid type, injection pressure) based on real-time treatment conditions and layer characteristics. This adaptive parameter adjustment optimizes fluid consumption by applying the right amount of fluid at the right rate to each layer, thereby maximizing production rate improvement while minimizing total fluid consumption compared to fixed non-adaptive schedules.
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 allows for a more accurate and efficient stimulation process, reducing the amount of fluid and time required to achieve optimal well production by dynamically optimizing the pumping schedule in real-time, ensuring that each layer is effectively treated and production rates are maximized.
Implementation Method 1
an acid pumped at a low pump rate can cause the radius of the wellbore to be increased by compact dissolution of the formation
Data Source
AI summary
A pumping schedule for stimulating a well can be dynamically optimized. For example, a layer in a well can be determined to have a highest value for a characteristic. The layer can be assigned as a first layer in an ordered list. A pump rate and type of fluid to pump into the wellbore for reducing an amount of blockage to below a threshold value can be determined based on a feature of the first layer. The blockage can reduce a flow of a production fluid from the first layer into the wellbore. Changes to values for the characteristics of layers in the well resulting from pumping the fluid can be determined. Another layer in the well can be determined to have the highest value for the characteristic as a result of pumping the fluid into the wellbore and can be assigned as the first layer in the ordered list.