Petrophysics software
Formation evaluation that stays inside the seismic project. Guided wizards for shale volume, porosity, permeability, saturation, pore pressure and lithology, each one running on one well or every well, each one storable as a workflow task — with the logs, the maps and the seismic in the same windows.
Industry-standard methods, named and parameterised.
The Petrophysics bar groups them into properties, lithology, geomechanics and logs. Each opens a modeless wizard, so the main window stays usable and results can be reviewed in the views between runs.
The whole interpretation in a single dialog whose tabs follow the calculation order — environment, shale volume, porosity, saturation, permeability, matrix and results — instead of one calculator opened after another.
Linear index, Steiber, Clavier and Larionov for Tertiary or older rocks from gamma ray; an SP baseline method when the gamma is unusable; and a neutron-density cross-plot method that projects each sample onto the clean-sand to shale line, for radioactive or feldspathic sands.
From density, neutron, sonic or a combination, with matrix and fluid values pre-filled from common lithology presets — sandstone, limestone, dolomite — and a tooltip of typical values on each field.
Archie for clean formations, Simandoux and the Poupon-Leveaux Indonesia model for shaly sands, total-shale on either the total or the effective porosity system, and dual water where clay-bound water carries real conductivity. Tortuosity, cementation and saturation exponents are all editable, and the output scale is fraction or percent.
Grouped by provenance: empirical porosity-irreducible-saturation relations, NMR methods, and core-calibrated transforms. The output curve is named after the method that produced it, so two estimates never blur into one.
Hydrostatic pressure, temperature gradient, overburden stress integrated from the bulk density with an offshore correction, and effective stress. Elastic properties add velocities and the Vp/Vs ratio, acoustic and shear impedance, the dynamic moduli and the two Lambda-Rho and Mu-Rho AVO attributes.
Eaton from the sonic against a normal-compaction trend, a resistivity ratio method, Bowers for unloading-driven overpressure, a sonic-porosity effective stress route, and a direct subtraction from an existing effective-stress curve.
Lithology interpretation assigns a lithotype code per sample from log value ranges, combined by AND, OR or method priority with a weighted threshold and a conflict rule, and definitions save as reusable templates. Mineral Volume Estimation inverts the log responses into mineral fractions plus pore space by constrained weighted least squares.
Trains a CatBoost gradient-boosted-tree model on wells that carry the predictors and the target, reports MAE, RMSE and prediction correlation, and shows per-curve prediction impact alongside a cross-correlation matrix. Saved models live with the project and fill the gap in the wells that are missing the log.
Nothing is interpreted before it is loaded properly.
Half of petrophysics is bookkeeping: which mnemonic is which curve type, which unit it is stored in, whether the depth reference is right. g-Space puts that work where it belongs — at import, and in an editor with a history.
Six steps from a LAS file to a curve worth modelling with.
Statistics beside the logs, and the same controls everywhere.
Every calculator on the bar shares one input layout, one way of limiting the interval and one way of reporting what happened — so learning the first one is most of learning all of them.
Every curve here is read somewhere else.
The sonic and density feed the synthetic, the markers tie the velocity model, and the porosity and saturation end up in the grid. These are the other topics in the g-Space workflow.
Questions, answered.
Which petrophysical calculations does g-Space provide?
Can a calculation be run across many wells at once?
Can a missing log be predicted from the ones a well does have?
How are logs cleaned and edited before interpretation?
Run the chain on your own wells.
Load the LAS files, classify the mnemonics once, and take shale volume through saturation across every well in one batch — take g-Space for a trial run, or talk to Geomage about a demo on your data.