Unconventional field development practices utilize an evaluation process that produces an optimal stimulation plan and well spacing, and estimates the anticipated production for every well that follows this plan. The operator is accepting two assumptions in this process; the production estimates and decline profiles are representative of the average well within the field, and the drainage around each well will be roughly symmetrical. Providing these assumptions are within an acceptable margin of error, expected profit margins will be deemed acceptable and any additional expenditures to validate these assumptions may compromise profit margins by slowing down operations and increasing costs without providing quantifiable benefits.
NarSysTech has developed a workflow that allows the operator to test the symmetrical drainage assumption by qualifying the time-dependent nature of reservoir drainage without jeopardizing the benefits of standardized operations. By accepting the production estimates and decline profiles assumption, a Production Potential Model (PPM) can be constructed from current reservoir data, that distributes the anticipated production within a fractal network of cells, that inherit the production characteristic of a producing well, and show how the reservoir will drain over the life of the field.
The ability to analyze drainage symmetry and forecast the spatial and temporal distribution of reservoir drainage for a recently completed well, allows the stages in child wells to be optimized. Where drainage volumes are predicted to exceed expected limits (eg. 200' in the following image), pressure sinks can occur that result in a high potential for ‘frac-hits’ from child wells. If these areas are recognized prior to stimulation, adjustments can be made to reduce the chances of a ‘frac-hit’ and increase production by reducing well interference. Conversely, where the stages in the parent well show lower than expect drainage areas (eg. 600' in the following image), an opportunity to adjust the stage treatments in a child well and increase the stimulated volume can result in a production increase. These two opportunities alone, can result in more consistent and significantly higher production from every well with minimal impact on operational efficiency.
This unique real-time modeling approach can be continuously refined as each new well is completed, providing an up-to-date view of the expected reservoir drainage volume, allowing operators to test the symmetrical drainage assumption on ever well. This patent pending technology does not require monitoring data, can be deployed at a fraction of the costs of current service offerings, and increases the reach of the evaluation process.