Integration of well test data into the static permeability model to improve simulation model quality.
Reduce history matching work before you even start.
Incorporate the flow capacity measured in well tests into the permeability model, eliminating arbitrary adjustments during history matching.
More realistic static model: the permeability model now reflects the flow capacity (kh) actually measured in the field, not only the petrophysical interpretation.
Eliminate arbitrary adjustments during history matching: avoid the artificial discontinuities introduced by manual permeability corrections in conventional history matching.
Preserved continuity of the original model: the applied corrections maintain the spatial structure and consistency of the original permeability distribution.
CONNECT-PermMatch is a native Petrel® plug-in that addresses a recurring gap in the reservoir modeling workflow: the lack of integration between well engineering data and the static permeability model.
Traditionally, the permeability model is built from logs, cores, and petrophysical correlations, without systematic incorporation of well test data (notably the flow capacity kh). The result is a static model that does not reflect the flow behavior actually observed in the field, pushing the problem downstream to the dynamic simulation stage. During history matching, the reservoir engineer ends up performing manual and localized permeability adjustments to reproduce well behavior, introducing artificial discontinuities in the distribution and degrading the geological consistency of the model.
CONNECT-PermMatch resolves this issue by updating the 3D permeability distribution to match the flow capacity at well locations with the values measured in tests, while preserving the spatial continuity and structure of the original model.
The plug-in is developed in partnership with Kelkar & Associates Inc., based in Tulsa, USA.
The CONNECT-PermMatch methodology performs a spatially consistent correction of permeability using well test data as a constraint, without compromising the continuity of the original distribution. Core capabilities include:
Zone by zone kh calculation on the static model: The algorithm computes the flow capacity of the 3D model at each well location, broken down by zone, generating the reference value to be compared with test data.
Mismatch ratio (R) calculation per well and per zone: For each well and each zone, the module computes the ratio R between the kh measured in the well test and the kh of the model. The value of R directly quantifies the divergence between the static model and the actual field observation.
Spatial interpolation of the mismatch via kriging: The set of R values at well locations is interpolated by kriging throughout the reservoir, generating a smooth 3D correction map. This approach ensures that the permeability update is spatially consistent, avoiding the artificial discontinuities typical of localized adjustments
Permeability update preserving the original structure: The R map is applied to the original permeability distribution, producing a new 3D property that respects the texture, anisotropy, and heterogeneity of the original geological model, now conditioned on the actual flow capacity of the wells.
Integrated Quality Control: The module generates comparative histograms of the original and updated kh, along with the full kh Ratio map, allowing the user to visually assess the impact of the correction before using the new model in simulation.
Petrel integrated inputs and outputs: Inputs: wells selected from the Petrel Input Pane, permeability property from the 3D Grid model, and kh data per well per zone from well testing analysis.
Outputs: kh Ratio map, updated permeability model as a new 3D property, and kh histograms (original and updated).
A consolidated tool in the E&P market, used by multiple operators worldwide in reservoir characterization and simulation modeling projects.
Commercial licensing via SLB Ocean Store, with direct technical support from the engineering teams at DeepSoft and Kelkar & Associates.