Lithological determination from wireline logs is often done by sophisticated computer programs,

but basic quick-look interpretation can be made by visual inspection of appropriate logs.

The best logs for lithological purposes are those that are (1) most influenced by rock properties

and (2) least influenced by fluid properties. The most useful of the commonly available logs are

Gamma ray

Spontaneous potential (SP)

Caliper

Formation density

Photoelectric absorption

Neutron porosity

(For more details on these logs, see Basic open hole tools. Also, Difficult lithologies covers

logging tool response in sedimentary minerals.)

Borehole imaging tools such as the Formation MicroScanner are invaluable for detailed

purposes, including bedding character and sedimentary structures, but are much less commonly

available. (For more details, see Borehole imaging devices.)

Contents

1 Gamma ray logs

o 1.1 Lithological responses

o 1.2 Log shapes

o 1.3 Problems and exceptions

o 1.4 Spectral gamma ray logs

2 Spontaneous potential (SP) logs

o 2.1 Lithological responses

2.1.1 Shale

2.1.2 Sandstone

2.1.3 Tight rocks

2.1.4 Log shapes

o 2.2 Salinity contrast

o 2.3 Other problems

3 Caliper logs

o 3.1 Property measured

o 3.2 Lithological responses

3.2.1 Sandstone

3.2.2 Sand

3.2.3 Shale

3.2.4 Coal

3.2.5 Carbonates

3.2.6 Tight rocks

3.2.7 Anhydrite and gypsum

3.2.8 Halite and potash salts

4 Formation density logs (Alone)

o 4.1 Property measured

o 4.2 Lithological Responses (Nonporous rocks)

4.2.1 Evaporites

4.2.2 Coal

4.2.3 Ironstone

4.2.4 Shale

5 Photoelectric absorption (Pe) logs property measured

o 5.1 Lithological responses

5.1.1 Sandstone

5.1.2 Limestone

5.1.3 Dolomite

5.1.4 Shale

6 Neutron porosity logs (Alone)

o 6.1 Property measured

o 6.2 Lithological responses (Nonporous Rocks)

6.2.1 Water of Crystallization (Evaporites)

6.2.2 Bound water in shale

7 Neutron and density logs combined

o 7.1 Crossplotting

o 7.2 Overlay presentation

7.2.1 Sandstone

7.2.2 Limestone

7.2.3 Dolomite

o 7.3 Lithological responses

7.3.1 Sandstone (Oil or Water Filled)

7.3.2 Sandstone (Gas-Filled)

7.3.3 Sandstone (Air-Filled)

7.3.4 Limestone

7.3.5 Dolomite

7.3.6 Shale

7.3.7 Coal

7.3.8 Complex rock mixtures

8 See also

9 External links

Gamma ray logs

The common radioactive elements—potassium, thorium, and uranium—are normally

insignificant in reservoir fluids, whereas they are important components of the rock system,

especially of clay minerals. Gamma ray logs are therefore a good indicator of mineralogy.

Lithological responses

The principal gamma ray responses are as follows:

Lithology Gamma Ray Values (in API units)

Sandstone (quartz) 15–30 (rarely to 200)

Limestone 10–40

Dolomite 15–40 (rarely to 200)

Shale 60–150

Organic-rich shale 100–250

Anhydrite, halite 8–15

Sylvite (KCI) 350–500

Coal 15–150 (any value possible)

Log shapes

Figure 1 Characteristic log shapes for different types of sand bodies set in shale, (a) Funnel

shape, coarsening upward. Note that this is the shallowest interval, so the shale is least

compacted. (b) Cylinder shape, blocky. Note that the SP log is featureless because the borehole

salinity is the same as formation salinity. (c) Bell shape, fining upward. Note that coal is present

in addition to shale.

The shape of a gamma ray (or SP) log through a sand body is often thought of as a grain size

profile. Three basic log shapes are recognized: funnel (coarsening upward), cylinder (blocky),

and bell (fining upward) (Figure 1). These three shapes can be subdivided into smooth (relatively

homogeneous) or serrate (with interbedded thin shales).

Log shapes typically reflect changing depositional energy from high (clean, coarser sand) to low

(shaly, finer sand). An interpretive jump is usually made from depositional energy to

depositional process and hence depositional environment. Often this jump is made without

seriously considering the intermediate steps. This can be dangerous. Each of the steps is highly

ambiguous and must be augmented by other evidence, such as unit thickness, associated rock

types, and overall depositional setting. Typically,

Funnel shapes imply upward-increasing energy, which may be found in distributary

mouth bars, delta lobe fringes, deep sea fans, and other environments.

Cylinder shapes reflect relatively constant energy levels and can include eolian dunes,

low sinuosity distributary channels, and beaches.

Bell shapes represent waning-current sequences, which can include alluvial point bars,

deltaic distributaries, and deep sea fan channels.

In fact, grain size has no effect on gamma ray logs. The log shapes reflect shaliness, that is, clay

and mica content of the sand. Because most sands reflect a hydrodynamic equilibrium, clay

content does usually correlate (inversely) with grain size. However, in the following examples,

clay content and grain size do not correlate, resulting in misleading log shapes:

Very fine, clean sand above coarser sand may show a cylinder shape.

Clay clasts concentrated near the base of a channel may give a funnel shape.

Clay added later due to bioturbation or mechanical infiltration at the top of a gravel may

create a bell shape.

(For more details on using log shape to interpret depositional environment, see Lithofacies and

environmental analysis of clastic depositional systems.)

Problems and exceptions

Radioactive minerals in sands, especially K-feldspar, zircon, and mica, can raise sand

readings as high as adjacent shales. Gamma ray logs may be useless in immature sands

derived from basement terranes. However, beach placers rich in zircon may be valuable

correlative markers if not mistaken for shale.

“Hot” dolomite, especially common in the Permian basin in the United States, may have

gamma ray values up to 200 API units, resembling shale.

Radioactive (KCl) muds raise the baseline gamma ray zero reading so that apparent

values for all rock types are increased, sometimes by about 20 API units.

Evanescent high gamma ray readings in sands, present on one logging run but vanished

some weeks later, have been observed especially in steamflood conditions. While

remaining enigmatic, these may be due to concentrations of radon in the pore space.

Spectral gamma ray logs

In this enhancement to natural gamma ray logging, the energy levels of incoming gamma rays

are counted in a series of energy windows, and an algorithm converts the energy spectrum to

count rates for potassium (%), thorium (ppm), and uranium (ppm). Spectral gamma ray logs are

most useful in identifying the following:

Clay minerals. Illite clays are rich in potassium, whereas smectite and kaolinite contain

thorium. The thorium to potassium ratio can distinguish illitic from smectitic shales and

so provide a correlation tool.

Organic-rich rocks. In shales, uranium enrichment is usually associated with organic

content and can be a tool for identifying oil source beds. Quantitative relationships

between uranium and organic content have been reported, but tend to be inconsistent.

Mica sand. Richly micaceous sands (such as the Rannoch unit of the Brent Sand in the

North Sea) appear shaly on gamma ray logs, but can be distinguished because the

radiation is all from potassium.

“Hot” dolomite. This type of dolomite can be distinguished from shale because the

gamma rays are principally from uranium. The chemical relationship between uranium

and the dolomite is unknown.

Natural fractures. Soluble uranium in pore water often precipitates on open fractures, so

thin intervals with high uranium count (a ―spiky‖ log) may mark a fractured interval.

Producing zones. As with natural fractures, uranium may precipitate on flowing

perforations, so a spectral gamma ray log run after years of production may show which

completed intervals are producing and which are not.

Uranium prospecting. Most of the ―uranium‖ signal actually comes from the tenth decay

process in the uranium series, the decay of bismuth-214. This is separated in time from

the original uranium by half-lives in excess of 109 years, so the relatively soluble uranium

may have moved away during the interim even though the log still records its presence.

Spontaneous potential (SP) logs

Lithological responses

Shale

Spontaneous potential interpretation depends on first recognizing shale, where fairly constant SP

readings form a straight ―shale baseline‖ on the log (Figure 1a). Its actual SP value is not

significant.

Sandstone

The potential differences around a sand-shale contact deflect the SP from the shale baseline. The

deflection is negative for a normal salinity contrast (borehole fresher than formation). Little

change occurs within a sand interval, so a clean sand shows a straight-line ―sand line‖ (Figure

1c). (For more details on SP shale and sand baselines, see Determination of water resistivity.)

Tight rocks

An SP log is of little use in the absence of boundaries between shale beds and permeable beds. In

relatively tight rocks (carbonates, evaporites, etc.), the SP wanders aimlessly, with no sharp

usable deflections.

Log shapes

Funnel, cylinder, and bell-shaped motifs resemble those previously described for gamma ray

logs. They are due to the qualitative shaliness indication given by the SP and can therefore be

interpreted in a similar way to the gamma ray (except for the following complications).

Salinity contrast

Contrasting salinity is critical for SP logs. Three scenarios are possible:

Fresh borehole fluid in a saline formation. Gives ―normal‖ SP.

Borehole salinity is same as formation. Featureless SP, very low amplitude, may be a

straight line, no obvious relationship to beds (Figure 1b).

Saline borehole in a fresher formation. Gives a reversed SP, where sands show positive

deflections from the shale baseline.

Other problems

In additional to salinity contrasts, other conditions can create problems in interpreting SP logs.

For example,

Baseline shifts. Although the value of the SP shale baseline is not significant, it will shift

if formation fluid salinity changes from one bed to another, making the log hard to

interpret.

Manual shifts. On occasion, the logging engineer adjusts the SP log scale to keep it

within the track.

Mud type. Water-based mud (with suitable salinity) is essential. Oil-filled or empty holes

have nothing to carry the SP charges.

Interference. Remanent magnetism within the winching system often ruins SP logs. Look

for a sine-form SP whose cycle length is the circumference of the cable drum.

Hydrocarbons. The SP is generated in water. High hydrocarbon saturation reduces the

SP, making sands appear more shaly.

Caliper logs

Property measured

For lithological purposes, the critical data are caliper readings relative to bit size. There are three

scenarios:

Hard, inert rock Hole in gauge Caliper = bit size

Soft or brittle rock Hole washes out Caliper > bit size

Permeable rock Mudcake builds up Caliper

Well-designed modern mud systems can minimize washouts, making caliper logs less distinctive

for lithological purposes.

Lithological responses

Sandstone

Consolidated sandstone is usually permeable, so expect mudcake to cause a caliper reading that

is about 0.5 in. smaller than the bit size. Bed boundaries are often accurately delimited (Figure

1).

Sand

Friable, unconsolidated sand may wash out, causing large caliper readings. Look for this problem

in young, shallow formations.

Shale

Shale frequently spalls into the borehole, especially in the minimum principal stress direction.

This leads to elliptical boreholes identifiable with multiple arm calipers, as on a dipmeter.

Coal

Medium to high rank coals are often brittle and well-jointed. Such joint blocks cave into the

borehole (Figure 1c) leaving deep washouts as thick as the coal seam (frequently only 1 ft or so).

Not all coals behave this way.

Carbonates

Carbonates often fail to show mudcake build-up despite good permeability because individual

vuggy or moldic pores are too large to trap mud solids. Mudcake builds up on the back walls of

such pores, not into the borehole. Sucrosic dolomite is the only carbonate that typically shows

mudcake on calipers.

Tight rocks

Tightly cemented beds, such as ironstones, siltstones, and carbonate concretions in sandstones,

are hard, inert rocks that remain in gauge.

Anhydrite and gypsum

Anhydrite and gypsum frequently remain in gauge if pure, but shaly intervals may be washed

out.

Halite and potash salts

Salt-saturated or oil-based muds may maintain the hole in gauge, but dilute water-based muds

result in severe dissolution leading to huge, unoriented washouts.

Formation density logs (Alone)

Figure 2 Characteristic log signatures for a carbonate and evaporite sequence. Hole conditions

are good.

Property measured

Measured density is the sum of the rock system density and the pore fluid system density.

Density values can therefore be used directly to identify lithology only when the porosity is

insignificant. In porous rocks, density must be interpreted in combination with neutron or other

porosity logs.

Lithological Responses (Nonporous rocks)

Evaporites

Individual evaporitic minerals (such as anhydrite, halite, sylvite, and carnallite) have well-

defined densities and generate straight-line density logs with little variation (Figure 2).

Coal

Coals are variable but always significantly lighter than 2 g/cm3. Thin beds give a pronounced

density spike, but may not resolve a true density reading (Figure 1c). Note that deep washouts

also give low-density spikes.

Ironstone

Concentrations of iron minerals such as pyrite and siderite give high densities, often in thin beds,

contrasting with surrounding rocks.

Shale

Densities of shales vary between 2.2 and 2.65 g/cm3 or more, increasing with compaction

induced by age and depth of burial (Figure 1). Overpressured shales, in which some of the

overburden load is borne by pore fluid, are undercompacted and have low densities relative to

normally pressured shales at similar depths.

Photoelectric absorption (Pe) logs property measured

Photoelectric absorption (Pe), measured by the newer formation density tools, is related to

atomic number Z, raised to the 3.6 power (Z3.6

). Consequently, very light components (pore

fluids) have negligible effect, making the log good for lithology. Unfortunately, heavy elements

have an enormous effect. Thus, a few percent of iron masks basic lithological differences, and

barite (usually with mud weights over 10 ppg) makes the log unusable.

Lithological responses

Sandstone

Quartz should read 1.7 to 1.8 barns/electron, but most other minerals can raise the value

substantially. Because they are usually present, the log is of limited value.

Limestone

Clean limestone reads about 5.0 barns/electron (Figure 2).

Dolomite

Dolomite should read about 3.0 barns/electron, providing an easy way to distinguish limestone

from dolomite (Figure 2) even if gas is present. Note that iron in ferroan dolomite increases

readings to resemble limestone.

Shale

―Average‖ shale reads 3–3.5 barns/electron, but values up to 7 or 8 barns/electron can be

obtained depending on iron content and accessory minerals. This large range makes the log of

limited value.

Neutron porosity logs (Alone)

Property measured

Compensated neutron porosity is primarily the combined hydrogen content of the rock system

and the pore fluid system. Lithology can therefore be interpreted directly from neutron values

only when porosity is insignificant. In porous rocks, the neutron log must be interpreted in

combination with other logs such as formation density.

Lithological responses (Nonporous Rocks)

Water of Crystallization (Evaporites)

Gypsum and anhydrite. The typical neutron porosity value in anhydrite (CaSO4) is close

to zero, but that in gypsum (CaSO4 • 2H2O) is much higher—up to 60%.

Potash Evaporites. Sylvite is anhydrous with a near-zero neutron porosity, but carnallite

(KMgCl3 • 6H2O) gives neutron values of 30% to 60%.

Bound water in shale

Some water in shales is chemically bound to clay minerals, whereas some occurs in micropores.

Both types raise neutron log readings but represent no effective porosity (Figure 1). Shales

consequently have high apparent neutron porosity, but values vary among formations. Often 40%

is a good shale cutoff limit, but shale values can be as low as 30%. A local cut-off can often be

established by calibration, such as from cores.

Neutron and density logs combined

Neutron and density logs each react to both lithology and porosity, so by analyzing the two logs

together, one can begin to distinguish lithology from porosity. Neutron and density logs, together

with a caliper measurement recorded by the density tool and a natural gamma ray log, are

commonly run as a combination. This is the most powerful of the commonly available log suites

for general purpose determination of lithology.

Crossplotting

Logging company chart books all include neutron-density crossplots that are easy to use for

clean (nonshaly) reservoir rocks. The plots are entered with a bulk density and an apparent

neutron porosity (should be environmentally corrected, but the corrections are usually

negligible). A rock type (sandstone, limestone, or dolomite) and a corrected porosity can be read

from the crossplot.

Overlay presentation

Manual crossplotting is tedious. A much faster way to visualize rock type is directly from the

overlay presentation in which both neutron and density logs are superimposed in the same log

track. To do this, a compatible scale must be used so that the porosity components of both logs

exactly overlay. Then any offset (or residual) between the two logs is attributable to lithology or

to the presence of gas.

Both tools are generally calibrated in limestone units, so the compatible scale is defined for

freshwater-limestone systems, with theoretical limits as follows:

All Porosity (H2O) No Porosity (CaCO3)

Neutron (p.u.) 100 0

Density (g/cm3 ) 1.0 2.71

In practice, porosities over 50% are seldom needed, whereas rocks with densities over 2.71

g/cm3 are common. Thus, with slight rounding, the usual compatible scale is

Neutron (p.u.) 45 30 15 0 –15

Density (g/cm3 ) 1.95 2.20 2.45 2.70 2.95

In high porosity areas with no dolomite, the scale is often slid across to the following range:

Neutron (p.u.) 60 45 30 15 0

Density (g/cm3 ) 1.70 1.95 2.20 2.45 2.70

On these scales, any offset of neutron and density logs is maintained regardless of porosity.

Offsets are due to rock differences in density and neutron-absorbing properties (capture cross

section). Ideal relationships for the three main liquid-filled porous rocks are as follows:

Sandstone

Density displaced 0.05 g/cm3 to the left.

Neutron displaced about 3 p.u. (porosity units) to the right.

Cross-over is two small-scale divisions on the usual log grid.

Limestone

Density and neutron overlay exactly.

Dolomite

Density displaced 0.175 g/cm3 to the right.

Neutron displaced 4–8 p.u. to the left.

Separation is four to six small-scale divisions on the usual log grid.

Other noncompatible scales are harder to interpret. One is the sandstone scale: the zero neutron

reading is aligned with 2.65 g/cm3. Also, the neutron log may, or may not, be calibrated in

sandstone units, reducing cross-over in sandstone by about two, or one, scale divisions,

respectively.

If the two scales do not have the same amplitude (60 neutron porosity units corresponding to a

range of 1 g/cm3), lithological interpretation should not be attempted from the overlay plot

because log separations then become a function of porosity as well as lithology.

Lithological responses

Sandstone (Oil or Water Filled)

Clean quartz sandstones give the typical two-division neutron-density cross-over with density to

the left of neutron (Figure 1). The addition of some clay (forming shaly sandstone) increases the

neutron reading, reducing log crossover or even reversing it to create separation. Check natural

gamma ray for evidence of increasing clay.

Heavier components such as mica increase the density, reducing log cross-over or even reversing

it to create separation. Check spectral gamma ray to distinguish the following:

Mica: potassium radiation only.

Zircon (with other heavy minerals): thorium or uranium radiation.

Siderite, pyrite, etc.: no increased radiation.

Use the shape of the neutron-density cross-over to provide depositional energy in the same way

as an SP or gamma ray log (Figure 1). Thus, a ―V‖ shape is a funnel (coarsening upward) and a

―Λ‖ shape is a bell (fining upward).

Sandstone (Gas-Filled)

Compared to oil- or water-filled sandstone, the neutron log for a gas-filled sandstone reads as

much as 10–15 porosity units too low, and the density log may read about 0.05 g/cm3 too low.

Together these effects increase the log cross-over from two to about five scale divisions.

Sandstone (Air-Filled)

Nonhydrocarbon gas in sandstone can give neutron readings close to zero, depending on residual

water and humidity in the pore space. Enormous log cross-over results.

Limestone

Clean limestone has no neutron-density separation (Figure 2). When the neutron drifts to higher

values, expect the presence of clay. Check the natural gamma ray. In gas-filled limestone, expect

cross-over like that described for sandstone, and use a Pe value of 5 to confirm limestone.

Dolomite

Characteristic four to six scale division separation with density to the right of neutron is

relatively consistent in clean dolomite (Figure 2). Gas reduces or eliminates the separation; use a

Pe value of 3 to confirm dolomite. Locally high natural gamma ray looks like clay, but if

neutron-density separation is unchanged, it may be ―hot‖ dolomite (especially in the Permian

basin). Check uranium if spectral gamma ray is available.

Shale

Shale shows a log separation with neutron to the left of density, sometimes displaced by a large

amount (Figure 1). At times the separation is only three or four scale divisions, which can

resemble dolomite. To distinguish shale, check for the following:

Apparent neutron porosity is too high for the area. Shale neutron readings are often

between 30 and 50 porosity units.

Caliper log shows washouts.

Natural gamma ray is high; consistently high in beds where neutron is high. If spectral

gamma ray is available, look for all radioactive elements elevated (contrast only uranium

high in ―hot‖ dolomite).

Coal

Neutron and density logs for coal both read similar very high apparent porosities (Figure 1c).

Coals give prominent deflections that do not resemble anything but severe washouts. (Diatomite

has a density of about 1.4 g/cm3 and a neutron measurement of about 60 porosity units, so

crossover is at least seven scale divisions.)

Complex rock mixtures

Using neutron and density logs to resolve porosity and lithology allows only a ―one-

dimensional‖ view of lithology. Rock mixtures always create ambiguities for this simple quick-

look interpretation. Local knowledge of rock types and mixtures to be expected and not to be

expected may eliminate ambiguity (for example, do not look for dolomite and evaporites in a

temperate, humid delta). Rock sample and mudlog data are invaluable. For complex rock

mixtures, more input log data are needed, and computer-processed multidimensional crossplots

must be used to determine lithology. In any case, confidence is always increased by using more

input data.