Unconventional reservoirs
Total organic carbon and kerogen volume computed between shale volume and porosity, so the porosity models subtract the kerogen, net pay can cut on richness, and the zone table carries TOC and gas in place into Volumetrics.
Shale and tight plays fail on conventional workflows in a specific way: kerogen reads as porosity on the density log, uranium reads as clay on the gamma ray, and TOC is estimated in a side tool that nothing downstream can see. The organic-matter step fixes the order of operations. It runs after Vsh, reuses the shale points you already picked, hands the kerogen volume to the porosity models, and puts TOC, organic-rich thickness and Langmuir gas in place on the same zone summation that feeds Volumetrics. Everything runs in the browser on a project folder you choose; well log files never leave your computer.
The organic-matter step is part of Formation Evaluation and is included from the Starter plan, with the adsorbed-gas term in Volumetrics. See pricing
Every estimator is a continuous curve along the well, and the fused answer says how much to trust it at each depth:
Import core TOC, Rock-Eval and vitrinite reflectance and the workspace crossplots each estimator against it: the delta-log-R slope gives the maturity, the density trend gives the organic-free and kerogen densities, the uranium trend gives its regression, and the fused curve takes a linear calibration you can see the residuals of. A maturity dialog fits Ro against depth so deep source rocks are not read at the shallow maturity, charts HI against Tmax for kerogen type, and shows the S1 over TOC oil crossover. Excluded points stay excluded across every fit. The calibrated parameters go into the interpretation, so the uncertainty panel re-samples them through porosity, saturation and net pay rather than around the TOC alone.
Formation Evaluation
The workspace the organic-matter step runs in: Vsh, TOC, porosity, saturation and net pay.
Geomechanics
The 1D mechanical earth model that computes the brittleness indices and the mud weight window.
Volumetrics
Free plus adsorbed gas in place, deterministically and by Monte Carlo, from the bridged zone averages.
No. It is a step of the deterministic interpretation route in Formation Evaluation, between Vsh and porosity, switched on per case. A conventional well never sees it. It is included from Starter, and the adsorbed-gas term in Volumetrics comes with it.
Resistivity, sonic or density, and gamma ray give you Passey. Spectral gamma ray adds the uranium method, and density adds Schmoker. Core TOC with Rock-Eval or vitrinite reflectance for at least one well in the play is what makes the maturity and the calibration defensible; without core the workspace says so and runs Passey at the maturity you type.
A tight, clean carbonate produces a resistivity separation that is not organic matter. The step discounts the overlay methods above a resistivity cap and in gas zones, flags the sample with the reason, and lets you give that zone its own baselines in the parameter table. The synthetic test well carries exactly that trap, and the recovery test checks the carbonate is not booked as source rock.
No. Formation Evaluation reports adsorbed plus free gas per zone for the summation. The bridge carries only the adsorbed gas content to Volumetrics, which computes free gas from its own porosity, saturation and Bg and adds the adsorbed term on the rock volume. Each term is booked once.
In the geomechanics workspace, where the elastic moduli are. Rickman elastic brittleness comes from the model's static Young's modulus and Poisson's ratio; the mineralogical index (Jarvie, or Wang and Gale with kerogen as ductile) reads the probabilistic solver's mineral volumes when you have run it.
Load a shale well from a folder on your machine, switch on source-rock mode, calibrate to core, and carry TOC and gas in place to Volumetrics without re-typing a number. Included from Starter.
