MicroSeismic, Inc. is the leader in completions evaluation, having helped customers optimize production in every major basin in North America and 18 countries worldwide.
MicroSeismic’s new Completions Evaluation Services help our customers go beyond the dots in a box. Our descriptive and predictive services provide advanced interpretation integrated with well and treatment information that provide valuable insights and recommendations into treatment plans, helping to evaluate the success of every well, stage, and pad. This allows for continually improved fracture design, treatment, and ultimate recovery.
Descriptive Completions Evaluation
MicroSeismic’s Descriptive Completions Evaluation Services offer the most complete and detailed description of the results of stimulation programs to help understand productivity, reduce lifting costs, and minimize exploration risk. Integrated with well and treatment information, our services allow you to better understand ideal well spacing, improve your treatment plan, and increase ultimate recovery.
Productive-SRV combines engineering data with microseismic data to determine what proportion of the total stimulated rock volume (SRV) is propped and should, therefore, be productive. This novel approach helps you to finally answer the question “where did the proppant go?”
We utilize the failure type through the full moment tensor, how the rock broke, through MicroSeismic’s patented PSET® technology. From there, our team of experts build an event magnitude calibrated Discrete Fracture Network (DFN), taking into account the seismic energy of the fractures, rock properties, and the injected fluid volume. The technology then determines what part of the reservoir was affected by the treatment and what part of the reservoir may not be hydraulically connected over a longer period of time. Using reservoir characteristics from microseismic data allows for mapping the propped network, and therefore productive, fractures. This process helps operators estimate where the proppant is distributed throughout the fracture network to:
- Optimize production faster by determining ideal well spacing early on
- Maximize recovery by achieving ideal fracture coverage
- Compare and adjust different treatment designs and plans
Treatment Design Analysis
Treatment Design Analysis maps the microseismic event cloud in all three dimensions. This analysis allows tracking of growth in the fracture network in the horizontal, longitudinal, and vertical directions. This information is analyzed along with treatment data such as pressure and rate to allow for additional recommendations on field-wide completions optimization.
- Evaluate fluid system and treatment to track fracture growth
- Determine optimal stage length and spacing
- Identify optimum landing zone and vertical coverage
Cumulative Fracture Analysis
Cumulative Fracture Area Analysis uses data calculated from the discrete fracture network (DFN)to improve treatment and optimize completions. Used to help engineers determine how their cumulative fracture area grows with injected fluid volume, clients are able to compare and maximize efficiency across all wells.
- Determine if more fluid is needed to reach ideal fracture area
- Differentiate instant versus reactive stages, stage-by-stage
- Easily identify fault reactivation
Production Productivity Log
Performed on a per-stage basis, the Production Productivity Log allows the engineer to understand the productivity potential of each stage and provides realistic constraints to reservoir simulation models – improving production forecasting and reserves estimation.
Predictive Completions Evaluation
MicroSeismic, Inc.’s Predictive Completions Evaluation Services predict future production from the stimulated reservoir through a numerical production simulator using PermIndex and Productive-SRV as inputs, all within a few days after hydraulic fracturing.
Now operators can assess the success of operations early and in a more meaningful way by accurately estimating productivity for each well in units of hydrocarbon volume. This gives E&P companies the control to balance completion and stimulation parameters with production goals and economic hurdles, saving time and reducing exploration risk.
PIndex is a metric that quantifies the relative productivity for each stage of the completed well. Using a client approved pressure decline curve and the requisite fluid and rock properties, an unscaled estimate of production over time from any stage, well, or pad can be achieved. Such an estimate can be made within days of the completion and gives a robust indication of the relative productivity of each stage, well, or pad.
Production Forecast is a numerical prediction of a stimulated reservoir’s future production volume and rate. This calculation quantifies when and how much production can be expected from a completed well, including total EUR. The prediction is available immediately after well completion, enabling operators to promptly adjust planning for the rest of the field according to financial goals or economic climate.
DIndex is an estimate of a well’s future reservoir drainage volume. This calculation shows how the well is expected to drain the reservoir as it is produced, including the incremental and total volume that will be drained and the drainage pattern that will be created in the reservoir over time. This information allows for planning ideal well spacing based on the desired timing of production or competing drawdown pressures in adjacent wells.
Geomechanics Completions Evaluation
The magnitude and direction of maximum horizontal stress have a significant effect on the final stimulation pattern in unconventional reservoirs. Fracture propagation and interaction with natural fractures are largely controlled by maximum horizontal stress direction and the difference between its magnitude and that of the vertical and minimum horizontal stresses.
MicroSeismic’s stress analysis service uses the moment tensor for each microseismic event and a mathematical inversion technique to calculate the field’s undisturbed maximum horizontal stress. This technique is able to detect and exclude the inconsistent event focal mechanisms caused by stimulation, which are typically the main problem preventing accurate determination of undisturbed field stresses.
Knowing the undisturbed maximum horizontal stress of the reservoir enables operators to optimize a wide range of completion parameters, including stage length, pumping pressure and flow rate, because of the influence the maximum horizontal stress has on fracture propagation.
To learn more about Completions Evaluation, please contact MicroSeismic.