Vshale (and not Vclay), is what is normally estimated in well logging. In a stratigraphic column —particularly in clastic environmets— it is common to find pure shales (100% VSH sediments). Those shales are tight rocks (say sealing, with permeabilities in the range of nano-Darcies), that are built mostly of clays, and minor proportions of tiny hydrogen free silt size particles (up to around 0.06 millimeters of "rock dust"), with quartz (SiO2) and some lithic minerals like feldspars and plagioclases.
A typical pure gray shale rock, usually contains 65% of clays or more (like illite, smectite, chlorite, and kaolinite). Shalines or clayness indicators derived from gamma ray, and hydrogen neutron-density porosity, respond mostly to the presence of clays, not to the presence of silt particles —clays trap traces of GR emitting minerals, and clays have hydrogen in their chemical formulae—
That maximum indicator response detected on a pure shale, does not mean that the shale is built 100% only with clays (even mudstones and claystones are not 100% clay). The maximum signal of the indicator is related to a maximum of 100% shale sediment that has blends of clays and silt, seldom a maximum of 100% of clay.
Unless a rock body with almost 100% of clay content is found to tie to a log indicator, there is not normally an easy way to estimate directly Vclay, nor to differentiate what is silt and what are rock grains. They have the same non-clay minerals: they only differ in their size. To estimate Vclay, a companion independent piece of information is needed. On way is to access lab data:
- Take a pure shale rock and bring it to a lab. Make sure it is indeed a pure shale, i.e. only clays and silts, without rock grains, sands or shaly sands.
- Analyze the sample and measure the proportions of all minerals. X Ray Diffraction (XRD) is one of the preferred techniques for this, but you may also try with electric microscopic imaging techniques, or perhaps thin sections.
- Sum all the clay mineral proportions and all the non-clay (silt) mineral proportions.
- Define pSilt as the ratio between the non-clay (silt) minerals to the rock total (clays + silt). The correct proportions to take should be volume proportions instead of weight proportions. However, they usually produce somewhat similar numbers for practical log practices.
- Then, assuming that the shale sediments (the clay sediments + silt sediments blend) nature and its proportions in the pure shale rock (VSH=100%) are approximately similar to the ones in shaly rocks (VSH < 100%), we can estimate Vclay (VCL) by:
- Notice that only if pSilt=0, VCL=VSH, which seldom occurs. If the clays and silts nature, distributions, and proportions are significantly heterogeneous throughout the reservoir, then pSilt is no longer a constant, but the former approach can still be applied by modeling pSilt as a space variable, that is, pSilt = pSilt (x,y,z) should be estimated and interpolated in the reservoir.
Most shale rocks have pClay > 0.65. That is, pSilt = SILTprop < 0.35. GeolOil defaults pSilt=0.25 and pClay=0.75 for many of its internal equations and mineral solvers. You are welcome to replace this default value with a custom lab measured one, or even use a pSilt(z) LAS curve on its own right instead of a constant.
The following table shows an example of an XRD lab result proportions of a gray shale from a shallow, clastic fluvial environment, shown in the top zone of the left photograph, on regular light.
For the table above, pSilt=0.16+0.01=0.17 (17%), and pClay = 0.83 (83%)
The top zone is a classic pure shale, so VSH=1.0, and VCL = pClay * 1 = 0.83. In spite that pSilt=0.17 >0, the silt size particles of quartz and feldspar are so tiny that still conforms a perfect seal that stopped oil upward flow migration (and also has a fully impregnated irreducible water saturation that traps the formation water, so SWt=1.0 and SWirr=1.0 in the shale).
The bottom zone of the photograph, is a shaly sandstone (0 < VSH < 1, far to be a clean sand), in which the oil resides (the black stain in regular light indicates oil). By gravitational segregation, the oil tries to flow upwards (because oil is less dense than water), but the shale above blocked the migration, conforming a reservoir trap.
This shaly sand needs a VSH adjustment to properly estimate its water saturation.
The image to the left shows a TS Thin-Section photograph from an optical microscope,
of a moderately clean sand from a braided channel system.
The image to the left shows a SEM Scan-Electronic-Microscope photograph of a tight, very shaly sandstone
from a braided channel system.
The image to the left shows a SEM Scan-Electronic-Microscope photograph of a clastic, sealing gray shale.