Once you have any GeolOil license (even a trial license), you may acquire
our affordable server access service to an extra data set examples of fully interpreted well logs. The server access
will last until the life term of your license.
Even if you regularly use another commercial petrophysical software, it is a handson valuable tool to understand petrophysical
concepts, interpretation and computation workflows. Learn how to compute porosity from different sources, matrix density,
shaliness, mineral proportions solvers, scripting, and produce nice log displays. The data collection is continuously
growing with key cases from naturally fractured reservoirs, clastic reservoirs, carbonate reservoirs,
unconventional tight, and shale oil reservoirs.
LEARN SET: Lifetime access to extra data set of examples. Requires a GeolOil license

Lease term

Price

Lifetime

Only $ 36



HIGHLY RECOMMENDED:
This server service of optional access to the log examples
extra data set is continuously updated and growing. It contains fully interpreted and processed
logs with nice displays, equations workflows, scripting algorithms and upscalings. Quickly learn how to compute fracture porosity,
use mineral solvers, and more. Once you acquire the access to the learning data set, it will be available for the
lifetime term of your license. We regularly put new examples that you can install with a single click from your license.
NOTE: The extra data set is only intended for selflearning purposes. It must not be redistributed.
You purchase a server access to the extra data set for learning. The data set itself is not sold.
Following down is a selection of some relevant processed log examples, that ships out of the box with the Learn Set:
1. A clastic braided channels reservoir with a clay mineral solver.
2. A tight reservoir with a carbonate mineral solver and shale oil.
3. A carbonate and eolian reservoir with mineral solver and estimation of matrix density.
4. A clean eolian reservoir with indicator curve flags for netsand and netpay
5. An eolian reservoir with water saturation computed through the
SW ratio method without porosity
6. A gas reservoir with porosity computed through five different methods:
the Porosity in flushed zone equation from microresistivity,
density porosity, neutron porosity, sonic porosity, and its benchmark against expanded core porosity on surface.

A clastic braided channels reservoir with a clay mineral solver.
✔ GLOG File: claySolver.glog
This example shows how estimate the major different clay minerals of a clastic reservoir.
The last two log tracks display the clay composition through the semiquantitative technique of XRay diffraction, and
the solution found by the GeolOil clay mineral solver. Clay discrimination is always difficult. However
the mineral solved estimations, show a reasonable qualitative match against the XRay diffraction reference track.
The most dominant found clay is smectite. However, around the depth MD=1820 ft., the mineral solver correctly detected the
presence of the clay mineral kaolinte, which is particularly difficult to detect as its Gamma Ray response is usually low
due to its low Cation Exchange Capacity. Notice on the first Lithology track, how low is the GR Gamma Ray
signal compared with signal yielded by a neutron porosity minus density porosity estimator
VSH. See the log plot below ↓
The functions panel workflow below shows all the functions and equations used, including
the volume of shale VSH that was computed combining the contrast between neutron porosity and density porosity estimator,
with a GR based Larionov VSH estimator:

A tight reservoir with a carbonate mineral solver and shale oil.
✔ GLOG File: shaleOil.glog
This example shows a typical workflow to process a tight reservoir with a mineral solver for clay and carbonate
minerals. Also the deeper zone has a shale oil play for which TOC Total Organic Carbon is computed using
the Schmoker equation calibrated with laboratory pyrolysis data. The track Minerals shows a reasonable
agreement between mineral proportions estimated by lab XRD XRay Diffraction, and GeolOil mineral solver ↓
The sequential functions panel workflow below ↓ shows the steps that produce the interpretation.

A carbonate and eolian reservoir with mineral solver and estimation of matrix density.
✔ GLOG File: RHOM1_WebExample.glog
An accurate estimation of the matrix density RHOM ρ_{m}
is a fundamental task for any petrophysicist.
In complex reservoirs ρ_{m} is no longer an approximate constant value inferred from the depositional
environment, but significantly varies with depth. That is ρ_{m} = ρ_{m}(depth).
Once RHOM is estimated, it is used to compute porosity and water saturation —and also to estimate permeability—
The brown rightmost last track "RHO matrix" on the log plot below shows how to estimate the matrix density RHOM ρ_{m}
using only well log curves, without any core lab measurements available ↓
The sequential functions panel workflow below shows the steps that produce the interpretation.

A clean eolian reservoir with indicator curve flags for netsand and netpay
✔ GLOG File: wellExampleNetPay.glog
The example below ↓ shows a log plot with indicator curve flags
(GeolOil exclusive trilean logic: 1 for no, +1 for yes, 0 for inconclusive) for netsand and netpay.
After computing cutoffs for porosity and water saturation
—this eolian rock is very clean, so computation of Vshale cutoff is waved: GR here does not read clay,
but remnants of organic bioradioactivity and signal noise—,
the indicator flag curves are produced with the Filtering & Upscaling module.
The Upscalings Panel workflow below ↓ shows the steps that produce the indicator curves

An eolian reservoir with water saturation computed through the SW ratio method without porosity
✔ GLOG File: Sw_Rxo_wellB.glog
The example below ↓ shows in the fourth track, the water saturation computed by the technique of the
SW ratio flushed zone method without using porosity (the red curve),
and its comparison the water saturation computed by the
Indonesia equation that uses porosity (the aquamarine curve). The agreement
between those curves is good, especially where the rock is less clayey.
The sequential functions panel workflow below ↓ shows a snippet of the steps that produce the interpretation.

A gas reservoir with porosity computed through five different techniques
✔ GLOG File: Phi_Rxo_and_Gas_DTF.glog
The example below ↓ compares on the third track, five porosity computations from different methods:
porosity from microresistivity, density porosity, neutron porosity, sonic porosity, and core porosity.
Notice that the sampled core plugs seemed to be expanded at surface, increasing slightly the correct insitu porosity.
The sequential functions panel workflow below ↓ shows a snippet of the steps that produce the interpretation.

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