CobraFlow

CobraFlow performs upgraded geologically meaningful simulations using algorithms developed by IFP and the Center of Geostatistics of the Paris School of Mines. CobraFlow produces the finest models on the market and uses the best upscaling methods to generate simulation models.

Embedded in the reservoir optimization process with CondorFlow, EasySense and PumaFlow, it helps keep a geological model consistent with the simulation model all along the study. This greatly helps when it comes to add new drilled wells in the model.

CobraFlow enriches the history matching loop performed by CondorFlow and EasySense. In some cases, modifying only simulation parameters leads to building a non realistic model even when match is obtained. CobraFlow may modify any static property and be included in the assisted history match process.

CobraFlow not only embeds the best in class methods from IFP for non stationary lithotype simulations, but also all the classical methods used on a daily basis in the whole industry, such as krigging, drawing in a distribution, sequential Gaussian simulations, deterministic methods etc.

As for the upscaling, CobraFlow was designed with the same focus. Consequently, CobraFlow not only proposes the cutting edge methods from IFP, but also usual methods like average power, Cardwell and Parson, etc.

Cobraflow

Success Stories

After 3 years of production, results indicated necessity to refine the geological model of Cretaceous turbidite reservoirs in an off-shore oil field of Campos Basin, Brazil.

A stratigraphic analysis was developed to build a new stratigraphic-structural framework. Seismic interpretation was used to incorporate structural data by mapping the system of normal faults. Using concepts of sequence stratigraphy, seismic, lithostratigraphic and lithologic data were used to define 12 major depositional sequences where 12 turbidite systems were recognized and 9 of them focused for the present study.

These turbidite systems compose the operational reservoir zones. Three unconformities affect the distribution of the turbidite systems. Action of erosion and faulting results in complex framework and lateral communications among reservoirs of different ages. Several oil-water contacts are present and controlled by some of the faults and the lateral communications.
Modeling this complex system included many different techniques and software in steps of the work.

The first step involved a topologic three-dimensional construction, including all of the major geologic information; relationships among the main turbidities systems were validated by production data. Next was creating a refined grid to populate the model with rock-properties; corner point geometry grid was built to honor the direction of major faults.

Third was facies characterization; vertical proportion matrix was used to represent the horizontal non-stationary of the data and seismic amplitude was used as a constraint. Plurigaussian simulations were used to populate the model; this type of simulation is suitable to represent the multiple and non-sequential contact relations among facies.

The fifth step was using Monte Carlo simulation to fulfill the model with porosity and permeability, based on petrophysic histograms from well data, classified by facies. Upscaling the model was the last step in order to finally transfer the geological data to the flow simulator.

Results from the flow simulator are indicating better fitting between this new geological model and the present production data.