As part of MSI’s Real-Time Completions Evaluation workflow, MSI is utilizing a Real-Time Drainage Visualizer developed in collaboration with NarSysTech to provide a drainage forecast and assess treatment efficiency in terms of recovery. The Production Potential Model provides insights into wellbore interference and identifies by-passed reservoir in real-time to facilitate changes to the treatment resulting in increased production and ultimate recovery.
The patent-pending Real-Time Drainage Visualizer allows for the following:
- Constructing a Production Potential Model (PPM) that can be instantly updated at the end of each stage,
- Determining flow paths of hydrocarbons based on real-time microseismic events and focal mechanisms,
- Adjusting treatment parameters on-the-fly using real-time observations, and
- Customizing the treatment design for every stage to achieve optimum stimulation and recovery.
Frequently Asked Questions
How does it work?
The PPM is a finite element fractal representation of the reservoir where each element inherits the production characteristics of the well that will produce from it. The production start time for each element is based on its proximity to the well and flow characteristics based on focal-mechanism-derived fractures in the DFN. Utilizing a fast-marching method to determine optimal flow paths and relative start times for each element, it identifies a pathway back to the wellbore.
What data is it based on?
The minimum data required is a deviation survey, completions information, treatment information, a microseismic-derived DFN, as well as an area type curve.
How is the start time of each element computed?
Element start times are based on the distance to the perforations along the least tortuous path as defined by the flow characteristics of the element and computed using a fast-marching method.
How are the flow characteristics of each element defined?
Using the provided data, the number of fractures and fracture properties are used to determine the flow characteristics of each element within the PPM.
Does the PPM estimate well production in absolute numbers?
No. The PPM is designed to honor the supplied type curves for each well and show how that production is distributed throughout the reservoir volume to identify wellbore interference and by-passed resources.
How can log and seismic attribute data be integrated into a model?
Logs and seismic attribute data that provide information regarding the distribution of natural fractures along the borehole and within the reservoir can be used to weight the flow characteristics of reservoir elements and in turn enhance production where those elements intersect induced fractures.