Advancements in horizontal drilling and hydraulic fracturing over the past two decades have enabled operators to extract vast reserves once deemed uneconomical. Even with these technological breakthroughs, operators continue to seek incremental improvements—sometimes as little as 1%—in cost reduction and production enhancement. These optimization efforts have historically been driven by fracture models, however these models are often built on generalized reservoir assumptions. The true challenge lies in navigating the heterogeneous nature of unconventional plays, where reservoir variability significantly influences the creation and production potential of hydraulically induced fractures.
ShearFRAC®, in collaboration with their academia partners have developed an enhanced workflow to address these challenges. By embracing subsurface variability and using real-time data to refine fracture models, operators are provided additional pathways to optimize hydraulic fracturing operations, enhance well productivity, and improve return on investment (ROI).
The Challenge of Hydraulic Fracturing in Complex Unconventional Reservoir Environments
Fracture modeling is a valuable tool for predicting fracture geometry prior to completing a well or as a production match once on-line. These models provide a theoretical baseline, offering insights into fracture height, length, and area based on average reservoir parameters. However, unconventional reservoirs are characterized by substantial variability in properties such as permeability, porosity, and natural or previously created fracture networks from existing parent wells.
As operators move to full-field development, additional factors, such as depletion and stress shadowing, further complicate the modeling process. When multiple wells are drilled in proximity, the pressure changes in one well can influence the behavior of fractures in newly completed wells. These changes may be caused by depletion or stress shadowing that alter the growth and geometry of fractures, adding another layer of complexity to the equation.
The issue with traditional fracture models is that they are often derived from average reservoir properties, which fail to account for these complexities. As a result, they provide a generalized view of fracture behavior that is often misaligned with what is happening in the subsurface. In reality, most wells experience a mix of “good” and “bad” stages, with only a small percentage performing exactly as designed. This opens the door for enhanced understanding and adaptation to subsurface complexity, leading to more consistent well performance.
The Solution: Enhanced Data-Driven Workflow That Embraces Subsurface Complexity
ShearFRAC® has developed an advanced workflow that enhances the accuracy of fracture models by incorporating real-time pressure data from active and offset wells. This process involves two key techniques: Post-Fracture Pressure Decay (PFPD) analysis and Fracture-Driven Interaction (FDI) measurements. Both provide valuable insights into fracture geometry and behavior, allowing operators to refine their models and make data-driven decisions.
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Post-Fracture Pressure Decay (PFPD) Analysis
PFPD analysis involves monitoring the pressure decay in a well after hydraulic fracturing has been completed. This technique provides critical information on key parameters such as fracture length (xf), fluid efficiency, and formation permeability. By analyzing how pressure dissipates within the formation over time, operators can estimate the extent of fracture growth and assess how efficiently the injected fluid has stimulated the reservoir.
One of the major advantages of PFPD analysis is its ability to provide stage level insight into how fracturing fluid interacts with the reservoir following the fracturing process. This can be particularly useful in identifying areas of depletion or additional connectivity through fault structures or natural fractures to refine future completion designs.
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Fracture-Driven Interaction (FDI) Measurements
FDI measurements involve monitoring pressure changes in offset wells during active fracturing operations. These offset wells can be both on or off pad and provide additional understanding for spatiality of fracture growth. By measuring pressure response in adjacent wells, operators can gain insights into fracture length and cluster efficiency. This information is crucial for understanding the extent to which fractures from one well are interacting with others.
By combining PFPD and FDI data, operators are empowered with a more detailed and accurate picture of fracture geometry. This enhanced understanding allows operators to update their models in real-time, making it possible to adjust completion designs and optimize field development strategies on the fly.
Incorporating Subsurface Complexity into Completion Designs
By incorporating information derived from pressure measurements, operators are able to adjust their strategies based on actual well data rather than relying on assumptions or historical averages. This allows for the refinement of models to better reflect the true behavior of fractures in the subsurface.
This approach enables operators to embrace, rather than ignore, the complexities of unconventional reservoirs. Instead of relying on a one-size-fits-all fracture design, operators can now tailor their completions to the unique characteristics of each well or even more granularly at a stage level. This can involve adjusting variables within pump schedules such as rate, fluid volumes, proppant concentrations and chemicals to optimize fracture geometry and maximize stimulated rock volume (SRV).
For example, by identifying areas of the reservoir that are prone to stress shadowing or depletion, operators can adjust well spacing or landing depths to mitigate these effects. In some cases, alternate pump schedules can be used to take advantage of natural fractures or bedding planes, enhancing fracture growth and increasing production.
The Payoff: Boost to Capital Efficiency and Enhanced Well Performance
The ability to update fracture models in real-time and incorporate subsurface complexity into completion designs offers significant operational benefits. By optimizing fracture geometry and targeting productive zones more effectively, operators can enhance capital efficiency, reducing the amount of time and resources needed to achieve production targets.
Furthermore, this approach can help operators avoid costly mistakes, such as overstimulating unproductive zones or drilling too closely to depleted wells. By using real-time data to refine their strategies, operators can make more informed decisions about well spacing, frac size, and landing depths, leading to better well performance and higher returns on investment.
Unlocking a Smarter Path Forward to Hydraulic Fracturing Success
ShearFRAC®’s advanced pressure measurement technologies represent a step forward in the understanding of fracture geometry created during hydraulic fracturing operations. By embracing subsurface complexity and using real-time data to refine fracture models, ShearFRAC® enables operators to optimize completion designs, improve well productivity, and maximize the value of their assets.
In a world where reservoir heterogeneity and subsurface complexity can make or break the success of a well, ShearFRAC® offers operators the tools they need to navigate these challenges and consistently achieve high-performance results. Whether it’s adjusting pump schedules, refining well spacing, or updating fracture models in real-time, ShearFRAC® provides a data-driven, cost-effective solution that enhances operational efficiency and delivers greater ROI.