This page describes sonic travel time logs profiles, in the order of their appearance over the years. This presentation style provides insights into tool evolution, and a specific tool’s capabilities and limitations. You will find most these tool types in your well files – here’s your chance to learn more about them.


The first sonic logs appeared in 1954.Developed by Seismograph Service Corporation, Tulsa, Oklahoma, the tools  were called Acoustic Velocity Logs with a sound-pulse transmitter and a single sound receiver

Sonic logs, also known as sonic travel time logs or slowness logs, rely on the properties inherent in Snell's Law to propagate sound from a logging tool through the rock to receivers on the same logging tool. The speed of sound in rock is governed by the physical properties embodied in the Wood-Biot-Gassmann Equations. Some geophysicists call these logs velocity logs, but this is an obsolete term.

All sonic logs need a liquid filled borehole to operate properly. Older logs worked only in open hole, but  also could be used as a cement integrity log in cased hole. Modern logs can make most of their measurements in both open and cased holes.

Sonic logs measure the travel time of sound through the rock, recorded in microseconds per foot or per meter (abbreviated as usec/ft or usec/m, sometimes us/ft or us/m). The tool emits a sound pulse about once or twice per second from a transmitter. The first arrival of sound is detected at two or more receivers a few feet from each other and from the transmitter. The time elapsed between the arrival of sound at two detectors is the desired travel time.

The newest generation of sonic logs can use the first arrival detection described above, or a cross correlation of waveforms to determine travel time. In cross correlation, the shear, Stoneley, and mud waves can be located, as well as the usual compressional wave. In well-cemented casing, these sonic logs can be recorded through casing.

Some sonic logs show a velocity scale, often non-linear. Another log presentation portrays the sonic data as its equivalent porosity, translated with a particular lithology assumption. The scales are usually called Sandstone or Limestone scales to reflect the assumption that was made to create them. Dolomite scales also exist on a few logs. The relationships are:
      1: PHIS = (DELT - KS6) / (KS7 - KS6)
      2: DELT = PHIS * KS7 + (1 - PHIS) * KS6

  KS6 = 55.5 for Sandstone scale (English)
  KS6 = 47.3 for Limestone scale (English)
  KS6 = 44.0 for Dolomite scale (English)
  KS6 = 182 for Sandstone scale (Metric)
  KS6 = 155 for Limestone scale (Metric)
  KS6 = 144 for Dolomite scale (Metric)
  KS7 = 188 for English units
  KS7 = 616 for Metric units

. Continuous Velocity Logging
H.R. Breck, S.W. Schollhorn, R.B. Balim

Jjoint Annual Meeting AAPG-SEG-SEPM, New York, 28-31 Mar 1955.

2. Elastic Wave Velocities in Heterogeneous and Porous Media
     M.R.J. Wyllie, A.R. Gregory, L.W. Gardner,
Geophysics, Vol. XXI, No. 1 (Jan 1956).

3. Theory of Propagation of Elastic Waves in a Fluid-Saturated Porous Solid
     M.A. Biot, Journal of Acoustic Society of America, 1956

4. Sonic Logging
    M.P. Tixier, R.P. Alger, C.A. Doh, AIME, 1958

5. Velocity Log Characteristics
     A.A. Stripling, Journal of Petroleum Technology, 1958

Energy Sources for Acoustic Logs
The sound pulse from early sonic log sources was about 30 KHz. Newer tools use lower frequency, between
3 and 5 KHz. Acoustic log source types fall into three categories: monopole, dipole, or quadrupole, illustrated at right.

Monopole sources emit sound energy in all directions radially from the tool axis. They are sometimes called axisymmetric or radially symmetric sources. Commercial wireline sonic logging tools, from the earliest tool to the present-day, carry a monopole source along with two or more monopole receivers. This tool arrangement creates the conventional compressional sonic log that we are all familiar with.

Sound energy from the source that reaches the rock at the critical angle is refracted (bent) so that it travels parallel to the borehole inside the rock. This energy is refracted back into the borehole, and strikes the receivers. The difference in time between arrivals at the receivers is used to estimate the travel time, or slowness, of sound in rock. Sound velocity is the inverse of slowness.

In fast formations, this tool design can also receive shear waves generated in the formation, where some of the compressional energy is converted to shear energy. A fast formation is a rock in which the shear velocity is faster than the compressional velocity of the fluid in the borehole. A slow formation is a rock in which the shear velocity is equal to or slower than the fluid velocity.

The monopole source also generates a shear wave on the borehole surface in fast formations, called a pseudo-Rayleigh wave. The converted shear and the pseudo-Rayleigh arrive at the monopole detector with nearly the same velocity and cannot usually be separated. Monopole sources also generate the Stoneley wave in both fast and slow formations. The low frequency component of the Stoneley is called the tube wave. More detailed descriptions of all wave modes are given later in this Chapter.

Dipole sources and receivers are a newer invention. They emit energy along a single direction instead of radially. These have been called asymmetric or non-axisymmetric sources. They can generate a compressional wave in the formation, not usually detected except in large boreholes or very slow formations. They generate a strong shear wave in both slow and fast formations. This wave is called a flexural or bender wave and travels on the borehole wall.

Modern open-hole sonic logging tools carry both monopole and dipole sources and receivers so that compressional and shear arrivals can be recorded in slow and fast formations. The sources are fired alternately; the sound from one source will not interfere with the other.

Some modern sonic logging tools have two sets of dipole sources set orthogonally, with corresponding dipole receivers. Shear data can be recorded in two directions in the formation. These are called crossed-dipole tools. After suitable processing, the two acoustic velocity measurements are translated into a minimum and maximum travel time.

The ratio of these two travel times is a measure of acoustic anisotropy in the rock. This is an important property in stress analysis, hydraulic fracture design, fractured reservoir description, and tectonic studies.

Monopole (upper) and dipole (lower) waveforms in a slow formation. There is a compressional wave (P) but no shear arrival on the monopole waveform. The dipole waveform at the same depth shows no compressional but good shear (S) arrivals. Notice that the shear wave arrives after the fluid wave (the definition of a slow formation).

In a fast formation, the shear arrival will be seen on the monopole waveform as well as on the dipole waveform.

Quadrupole sources generate asymmetric pressure waves, called screw waves, which behave similarly to those of dipole sources. They can be used on open-hole tools, although no such tool is commercially available. They are more suited to the logging-while-drilling environment where recent developments have shown some success in measuring shear travel time. The quadrupole waves travel in the drill collar and the formation, the two being coupled through the annulus. At low frequencies the formation quadrupole travels at the formation shear speed. The quadrupole LWD tool collar is designed to be thick enough that the collar quadrupole mode is "cut off" (very highly attenuated) below some frequency chosen to be well above the frequency used for quadrupole logging, thus minimizing the interference with the formation quadrupole.

While there are strong collar arrivals on monopole LWD tools, there have been monopole LWD sonic logs operating successfully for many years, using various mechanical and processing techniques to attenuate the collar arrival. For LWD dipole tools, the collar mode interferes with the formation dipole, forming coupled modes where the formation shear speed is difficult to extract.


The velocity of sound varies with the frequency of the sound wave. This effect is called dispersion. Most waves travel faster at low frequency (normal dispersion) but tube waves are slightly reverse dispersive in fast formations and normally dispersive in slow formations.

Compressional waves have very little dispersion. The various wave modes used to measure shear velocity are very dispersive, which may account for errors in shear velocity on older logging tools, when high frequency sources were the norm. Today, tools are designed to work below 5 KHz for shear measurements, instead of 20 to 30 KHz on older tools. Typical theoretical dispersion curves for a particular velocity assumption are shown below to illustrate the problem. For larger boreholes and/or slower formations, the dispersion curves shift to lower frequencies.

Shear velocity dispersion curves for fast (left) and slow (right) formations.

Acoustic Transmission Modes from a Monopole Sources
The monopole source generates several wave modes, some of which have been used more or less successfully, to estimate shear velocity. Other wave modes are mentioned in the literature and described here to help clarify terminology. The following comments deal primarily with the monopole wireline tool, but dipole and LWD are mentioned briefly to contrast important differences.

Monopole sources can develop both body and surface waves; dipole and quadrupole sources create only surface waves. Body waves travel in the body of the rock. Surface waves travel on the borehole wall or bounce from the wall to the tool and back to the wall. The surface waves are also called guided waves or boundary waves.

1. Fast compressional waves , also called dilational, longitudinal, pressure, primary, or P-waves are recorded by all monopole sonic logs, beginning in the mid to late 1950's. They are the fastest acoustic waves and arrive first on the sonic wavetrain. Biot called these dilational waves of the first kind and are body wave. The velocity of this wave is related to the elastic properties of the formation rock and fluid in the pores. It has been used successfully for years as a porosity indicator.

The compressional wave is initiated by a monopole energy source and is transmitted through the drilling mud in all directions. Sound traveling at the critical angle will be refracted into the formation, which in turn radiates sound energy back into the mud, again by refraction. The sound waves refracted back into the borehole are called head waves. The compressional head wave is detected by acoustic receivers on the logging tool.

A dipole source generates a noticeable compressional wave in fast formations and in large boreholes, especially on tools running at higher frequencies. The wave is probably present in faster formations and smaller boreholes, but is below the detection level of most processing techniques.

The velocity of the compressional wave does not vary much with the frequency of the wave. The frequency spectrum of the wave depends on the source frequency spectrum and is usually in the 5 to 30 KHz range. Older tools generally used the higher frequencies, current tools use the lower.

An acoustic ray path is a line that traces the path that the sound takes to get from the source to the receiver. Compressional waves vibrate parallel to their ray path.

2. Slow compressional waves are transmitted, as well as the fast waves described above. It is called a dilational wave of the second kind by Biot. It is also a body wave and travels in the fluid in the pores at a velocity less than that of the fast compressional wave in the formation fluid. Its amplitude decays rapidly with distance, turning into heat before it can be detected by a typical sonic log. No pores, no fluid, no slow compressional wave. Although predicted by Biot in 1952, it was not detected in the lab until 1982 by Johnson and Plona. I am not aware of any practical use for this velocity in the petroleum industry.

The slow and fast compressional waves as described above should not be confused with the slow and fast velocities found by crossed-dipole sonic logs in anisotropically stressed formations.

3. Surface compressional waves , also called leaky compressional, compressional "normal mode", or PL waves, follow the fast compressional wave. This is a surface wave from a monopole source and travels on the borehole wall. Amplitude varies with Poisson's Ratio of the rock/fluid mixture. It is present in both fast and slow formations.

The wave is dispersive, that is, low frequencies travel faster than high frequencies. It has velocities that range between the fast compressional wave through the formation (Vp) and the fluid wave in the borehole (Vf). The first arrival coincides with Vp and the balance of the wave shows up as a "ringing" tail on the compressional segment of the wavetrain. It usually decays to near zero amplitude before the shear body wave arrives. This monopole leaky compressional wave is strongest in very slow formations, large boreholes, and boreholes with significant near-borehole mechanical damage.

The number of normal modes depends on source frequency; if frequency is too low, there will be no surface compressional wave. The first normal mode is sometimes called the least normal mode.

4. Shear body waves , also called transverse, rotational, distortional, secondary, or S-waves, are generated by conversion of the compressional fluid wave when it refracts into the rock from the wellbore. It converts back to a P wave when it refracts through the borehole to reach the sonic log detector. This wave is also a body wave. The refracted wave returning to the logging tool is called the shear head wave. Shear waves vibrate at right angles to the ray path.

Monopole sonic logs cannot detect a body shear wave in a slow formation (Vs < Vf) because refraction cannot occur. The modern dipole sonic log can generate a shear wave in all formations, but the shear wave is actually a surface wave called a flexural wave. A quadrupole source generates what is known as a screw wave with the same result.

When shear is missing on a conventional monopole log (and there is no dipole shear data), it can be estimated by a transform of the Stoneley wave velocity. However, the empirical formula ignores many of the minor variables, so the method is not very accurate.

Shear waves travel at a slower rate than compressional waves. Compressional velocity is approximately 1.6 to 1.9 times higher than shear velocity in consolidated rocks but the ratio can rise to 4 or 5 in unconsolidated sediments.

Shear velocity at sonic log frequencies is not very dispersive but the wave modes used to measure shear velocity are highly dispersive. Low frequency components are faster than high frequency components. Because even low frequency logging tool sources have a moderate frequency spectrum, the shear body wave will show the "ringing tail" effect on the shear arrival.

Dispersion is important to us for another reason. Lab measured sonic velocities are made at high frequency, usually 1 MHz, and logs make their measurements at low frequency, 3 to 30 KHz, so comparisons of the results from lab and log measurements is difficult.

The shear wave velocity from a sonic log can be used to predict porosity just like the compressional wave. This is not true for 1 MHz lab measurements because the wavelength is too small to treat the rock/porosity mixture as a single coupled material.

Shear velocity is relatively independent of fluid type, so there is no appreciable gas effect on the measurement, unlike the compressional wave, which has a large gas effect. Combined with compressional wave velocity and density data, all the elastic properties of the rock can be computed. Similarly, at seismic frequencies, the shear wave is not significantly affected by the fluid type in a rock so, like the shear sonic log, there is no gas effect on the shear seismic section. Thus, a gas related bright spot (direct hydrocarbon indicator or DHI) on a compressional wave seismic section will have no comparable shear wave anomaly. In contrast, a lithology related anomaly will have a corresponding shear wave anomaly. Thus, it is possible to use shear wave seismic data to evaluate the validity of direct hydrocarbon indicators.

5. Shear surface waves , also called pseudo-Rayleigh, multiple-reflected conical, reflected conical, or shear "normal mode" waves, follow the shear body wave. They are a surface wave generated by a monopole source. They are also classified as a guided-wave. Monopole sonic logs cannot generate a surface shear wave in slow formations for the same reason that they cannot generate a body shear wave. Dipole sonic logs can generate a different form of shear surface wave, the flexural wave, but cannot create the shear body wave.

These waves have also been called slow shear waves and shear waves of the second kind in a few papers. This usage should not be confused with the slow and fast shear velocity found by crossed-dipole sonic logs in anisotropically stressed formations.

These are called pseudo-Rayleigh waves because the particle motion is similar to a Rayleigh wave on the Earth's surface, but it is confined to the borehole surface. It may also be called a tube wave as it travels on the tubular surface formed by the borehole wall. This latter terminology can be confusing because Stoneley and Lamb waves are also called tube waves.

Surface waves on the Earth include Rayleigh and Love waves. Particles in Rayleigh waves vibrate vertically in elliptical retrograde motion and cause severe damage during earthquakes. They are also the principal component of ground roll in seismic exploration. Love waves vibrate horizontally, similar to a shear wave, and can be considered as a surface shear wave when found on the Earth's surface.

The number of normal modes depends on source frequency; if frequency is too low, there will be no pseudo-Rayleigh wave. The first normal mode is sometimes called the least normal (shear) mode.

This wave is dispersive, that is, low frequencies travel faster than high frequencies. The lowest frequency component arrives at shear velocity (Vs) and reinforces the shear head wave arrival, if one exists. The balance of the energy is dispersed over the interval between shear wave velocity (Vs) and fluid velocity (Vf).

The Airy phase of the shear normal mode (pseudo-Rayleigh) occurs just after the fluid wave. It can distort the surface shear wave and make it difficult to determine shear velocity. It can also distort the fluid wave and the Stoneley wave arrivals. I am not aware of any practical use for this part of the waveform in the petroleum industry, but it is mentioned often enough in the literature to warrant this brief description.

In the absence of a shear head wave, which may occur due to attenuation, the onset of the pseudo-Rayleigh wave is used to estimate shear velocity (Vs). If the onset of the pseudo-Rayleigh is low amplitude, Vs may be chosen a little further along the waveform, resulting in a slower value than the correct Vs. When both surface and body shear waves are transmitted, the surface wave may overwhelm the body wave, resulting again in a slow Vs determination. This problem was common in the early days of hand digitized full wave sonic logs, before the advent of computerized shear picking.

If the source does not transmit low enough frequencies, the fastest surface shear wave will be slower than the corresponding body shear wave. If the log processing system picks the surface wave instead of the body wave, it will give a slow Vs. Service companies make an empirical correction for this on flexural dipole logs, but not on monopole shear logs, before presenting the log to a customer.

The Slowness-Time Coherence or STC travel time analysis method, a form of cross-correlation for picking velocity or travel time from sonic waveforms, minimizes this problem. The newest sonic logs use a dispersion corrected STC process. On older logs without the low frequency source, Vs is probably too slow even when STC is used.

If the rock is altered near the borehole wall due to drilling or chemically induced damage, the surface shear wave will be slower than the body shear, which travels in the undamaged formation. A recent paper shows clearly that two shear arrivals can be seen on waveforms from a dipole sonic in young unconsolidated sediment - one through the altered zone, one through the undisturbed formation.

There are lots of reasons why a log might give too slow a Vs. This problem has been the bane of fracture design and mechanical properties calculations for years. As the shear velocity technology gets better each year, we may be able to generate more reliable results.

6. Stoneley waves are guided waves generated by a monopole source that arrive just after the shear wave or the fluid compressional wave, whichever is slower. The wave guide is the annulus between the logging tool and the borehole wall. They are also called tube waves or Stoneley tube waves, in some of the literature.

Various authors have shown the Stoneley wave in slow formations to be slightly dispersive (low frequency arrive faster than the high frequencies); in fast formations it is slightly reverse dispersive (high frequency arrives first).

Amplitude of the Stoneley wave depends on the permeability of the rock, among many other things. The wave motion acts as a pump forcing fluid into pores and fractures. Higher permeability absorbs more energy, thus reducing amplitude. There is no simple equation for calculating permeability from Stoneley amplitude.

7. Tube waves , also called Lamb waves or "water hammer", are the low frequency component of the Stoneley wave (in theory, the zero frequency component).

8. Fluid compressional wave or mud wave is the compressional body wave from a monopole source that travels through the mud in the borehole directly to the sonic log receivers. It travels at a constant velocity with relatively high energy. When it occurs after the shear arrival (Vs > Vf), shear detection is relatively easy with modern digital sonic logs.

9. Direct tool arrival is sound that travels along the logging tool body. The wireline tool housing is slotted to make the travel path, and hence the arrival time, too long to interfere with other arrivals.

In the LWD environment, the tool body cannot be slotted like an open hole tool. However, internal and external grooves, or holes filled with acoustically absorbent materials, are used to attenuate the tool body signal. This mechanical filter is designed specifically for the frequency content of the source. Separating the tool direct arrival is still difficult with monopole and dipole LWD sources. The LWD tool direct arrival is negligible at low frequencies for the quadrupole source when the collar wall is thick enough.


Attenuation of Sound Waves
ll waves continue to propagate until they are completely attenuated. Attenuation is caused by several factors:

1. Some energy is reflected back into the wellbore due to the change in acoustic impedance between the mud and the rock. The impedance of any material is equal to the product of its density and velocity. The greater the change in acoustic impedance, the larger the amount of reflected energy. Thus, not all energy is transmitted into the formation. In large or rough holes, the energy may be so low as to cause difficulty with the sonic log readings.

2. Some energy is lost due to internal reflection inside the formation when the sound wave strikes a fracture plane or a bedding plane.

3. Spherical divergence, which reduces energy by the square of the distance from the source, takes place only on body waves.

4. Absorption occurs on all waves, which converts the mechanical energy into heat.

5. Phase interference of one wave mode with another due to varying frequency components can attenuate portions of the wavetrain in a variable fashion.

6. Multiple ray paths through rough borehole or altered rock usually reduces sonic amplitude, but more rarely may cause additive interference.

7. Poorly maintained logging sondes, especially earlier generations of tools, can attenuate the transmitted or received signal, by causing poor acoustic coupling with the borehole fluid.

8. Gas entrained in the mud column, and gas in the formation, can also attenuate the sonic signal, sometimes causing poor logs (cycle skipping on older logs, missing or interpolated lo curves on newer tools.

Sonic logs may lose enough signal from these losses that they cannot record a log over portions of the borehole. This is less common with current tools than with earlier generations of sonic logs.


Types of Sonic Logging Tools
Modern sonic logs, often called dipole shear sonic logs, usually carry monopole and dipole sources, and generate the measured values for compressional, shear, and Stoneley slowness in different ways depending on the formation characteristics. Such a tool can give us all three measurements in both slow and fast formations.

Earlier tools, commonly called full-wave, array, or long spaced sonic logs, could give us all three measurements in fast formations but shear was not possible in slow formations. Shear could be estimated by a transform of compressional or Stoneley slowness, and this is still done today in many real situations where the dipole log is unavailable. Waveforms were recorded in digital form but were seldom preserved, so reprocessing is not usually possible.

Earlier still, conventional and borehole compensated sonic logs could provide compressional slowness values directly. Shear slowness in fast formations was derived by digitizing an interpretation of the waveform traces or a VDL display of the traces. Most of these tools were short spaced, so it was difficult to pick the shear as the tail of the compressional wave stretched into the shear region. Waveform traces or VDL displays were on film and difficult to process accurately.

The sonic logging tool consists of a mandrel with one or more sound transmitters and one or more sound receivers. The tool is lowered into the borehole on the end of an electrical cable which provides power and signal lines to the tool. The transmitters and receivers are piezoelectric ceramic bobbins wound with a coil.

When electricity is applied to a sonic log transmitter, it contracts, making a snapping sound similar to snapping your fingers. It is pulsed from 30 to 120 times per minute. The pulse is a short 5 to 30 KHz burst of energy which is free to travel in all directions from the tool. When the pulse hits a receiver, a voltage is created in the coil, which is measured and sent uphole as an analog or digital sonic waveform.

In sonic logging, the actual signal received from the transmitter is an algebraic sum of all waves arriving at the same receiver, and from all directions around the borehole. The image below shows the waveforms received on two receivers on one logging tool. The arrival times on each receiver vary with the distance from the source and the speed of sound through the rock/fluid mixture. Sonic logs must be run in a fluid filled borehole.

Sonic log ray paths and recorded wave forms

Sonic logs come in many flavors:
1. single receiver, single transmitter on a mandrel
2. double receivers, single transmitter on a mandrel - conventional sonic log
3. double receivers, single transmitter on a sidewall pad
4. double receivers, double transmitters on a mandrel - borehole compensated sonic log
5. double receivers, double transmitters circumferential configuration
6. multiple receivers, multiple monopole transmitters on a mandrel - array or full wave sonic
7. multiple receivers and multiple multipole transmitters – dipole shear sonic

The earliest sonic logs had only one transmitter and one receiver. The travel time that was measured with this tool included a variable length portion through the mud.  (far left). These logs serve no useful purpose unless special analysis techniques are used, but you might run across these logs in old well files. They are still run today as part of the cement bond log - don't use these either.

<== Single receiver sonic log showing sound path from transmitter to receiver through the rock

Comparison of single receiver
sonic (Y-axis) with 2-receiver sonic log, showing higher DTC of single receiver version


To overcome the borehole effect, two detectors were used (near right). The arrival time of the sound pulse at the two detectors are subtracted from each other, giving the travel time between the detectors. The mud travel times are canceled as long as the hole size is constant. In varying hole size, the mud travel times do not cancel and spikes occur on the log, as in the log shown at the right. Many well files contain such logs. They should be used with caution and MUST be edited before being used for any calculations. 

Some older two receiver logs did not divide the measured time (microseconds) by the distance between the receivers to get microseconds per foot (or meter). You have to do this in the computer after the log is digitized or else digitize it with a corrected scale.


By using two transmitters at opposite ends of the tool, and averaging the travel times from two sets of receivers (illustration at left), the spikes can be reduced. This tool is called the borehole compensated sonic log (BHCS) and was almost universally used from 1970 to 1990. The same log can also be run with the array sonic, full wave, and dipole sonic logs run today.

The sidewall pad sonic was intended to reduce borehole effects and give high resolution, 9 inches, versus 2 to 3 feet for conventional sonic logs. The circumferential sonic log was intended as a fracture finder. Both are rare in the well files, but keep your eyes open.

All tools described above record the compressional travel time. Some versions of the tools could record a full wave train. These were called full wave sonics or variable density log (VDL), which was a method for displaying the waveform as shades of grey (and had nothing to do with density logs). Unfortunately, the wave trains from these older tools were available only in analog form and could not be further processed automatically by computer. Shear travel time logs can be made by manual picking and digitizing of the shear arrivals on the wavetrain.

                           Identifying and picking shear travel time on full wave sonic

The spacing of a sonic log refers to the distance between transmitter and the center of the receiver array. The span is the distance covered by the receiver array.

The sound frequency and spacing between the transmitter and detectors determine the depth of penetration of the sound energy into the rock. Long spaced logs are usually run in large holes or in unconsolidated formations. Depth of penetration is usually in the range of several centimeters (3 to 8 inches); deeper for long spaced tools. Penetration is about one wavelength so lower frequency transmitters see deeper into the rock.

A typical BHCS sonic log is shown on the left, with caliper and gamma ray in track 1 and sonic travel time across tracks 2 and 3. There are no borehole size artifacts, but there are a few cycle skips - spikes on the log due to low amplitude signal strength that cannot be recovered accurately..



Typical conventional compressional wave sonic logs. At left, the log shows cycle skips (shaded red) probably caused by low amplitude signal due to fractures. Unshaded black curve is probably valid. red curve is sonic log from adjacent well, possibly with lower porosity. At right, a good sonic log with no cycle skips, showing how to read log values in thin beds.

Newer sonic logging systems, called full wave sonic or array sonic logs, provide access to more acoustic information than traditional tools. In the late 1970's, sonic waveforms were recorded digitally and processed to acquire compressional, shear, and Stoneley wave travel time. Note that these were still monopole sources, so shear could not be obtained in slow formations. An array processor is required in the logging truck computer in order to extract this information as the hole is logged. These measurements provide valuable information on rock types, gas zones, porosity, formation elastic properties, stress field around the borehole, permeability, and acoustic impedance.

The configuration of the array sonic system is shown below.

Array sonic tool and waveforms from 8 receivers.

The array sonic uses a monopole or axisymmetric source. The dipole sonic uses a somewhat similar array of receivers, but has a dipole or non-axisymmetric source in addition to a monopole source. The newest dipole sonic has crossed dipole pairs set at 90 degrees to each other and records shear data on two orthogonal axes.

A typical log showing compressional, shear, and Stoneley travel time is illustrated below.

Array sonic log with compressional, shear, and Stoneley travel times.

In a fast formation, where shear is faster than mud velocity, the array tool obtains direct measurements for shear, compressional, and Stoneley wave values. In a slow formation, it obtains measurements of compressional, Stoneley, and mud wave velocities. Shear wave values are then derived from these velocities. The log below shows a case where shear travel time measurement is spotty at best. With a dipole source, the shear wave is generated and measured more reliably in both slow and fast formations.

On conventional and borehole compensated sonic logs, the arrival time of sound at each receiver was detected by a process called "first-arrival detection". Arrival times from all available receiver pairs were subtracted to determine the interval  travel time between the detectors, then divided by the distance between the detectors. Only the compressional wave could be detected by this method.

To detect shear and other waves, a waveform cross-correlation technique called semblance processing was developed. A crossplot of the semblance values provides a map showing peaks reoresenting compressional, shear, and Stonley wave tracel times. These naos are created and processed every time the transmitter fires.

Array processor coherence maps to find compressional, shear, Stoneley travel time and spotty shear log . probably caused by fractures in an otherwise competent rock.

Dipole and array sonic processing software is designed to find and analyze all propagating waves in the composite waveform. The technique uses a digital semblance (coherence) method called Slowness-Time Coherence or STC to identify and align the multiple arrivals across the array, and to determine travel times of all coherent components of the waveforms. This concept is very similar to velocity analysis programs used in seismic data processing.

Digital first arrival detection can also be used to obtain compressional travel time, mimicking the analog first arrival detection (also called first motion detection or FMD) of older sonic logs.

In semblance analysis, a fixed length time window is advanced across the waveforms in small overlapping steps. For each time position on the first receiver waveform, the window position is moved out linearly in time across the array of receiver waveforms, beginning with a moveout corresponding to the fastest wave expected and stepping to the slowest wave expected. For each of these moveouts, a coherence function is computed that measures the similarity in the waves within the windows. When the time and moveout correspond to the arrival time and slowness of a particular component, the waveforms within the windows will be almost identical and will yield a high value of coherence.

Applying semblance processing to the waveforms produces the contour plot shown on the left side of the previous illustration. To translate this into a slowness log, the information is reduced to a value for each arrival detected. This process is repeated for each set of array waveforms acquired by the tool while moving up the hole, and is used to produce a continuous log. Because the tool has many receivers, waveforms from common depth points in the wellbore can be stacked to improve signal to noise ratio, similar to CDP stacking of seismic data.

On the dipole sonic, shear travel time is always obtained, even in slow formations, due to the different way that acoustic waves propagate from the dipole source. The dipole sonic log run in crossed dipole mode is the tool of choice for today’s logging program, but analysts are usually stuck with what’s already in the well file.

Dipole shear sonic tool and specifications

Colour VDLwaveform presentation with 3 travel time curves and STC maps

The elastic constants of rocks are often considered to be uniform in the three cardinal axes. Under this assumption, a sonic log would read the same value in all directions. However, in a rock under horizontal tectonic stress, there is a minimum and a maximum stress direction, and the acoustic properties vary with that stress. Using the crossed dipole mode of the dipole shear sonic log, we can provide acoustic velocity (or travel time) in these two directions.


Example of a dipole shear image log run in crossed dipole mode. It has two compressional and two shear curves measured in orthogonal directions. An anisotropy coefficient can be computed from the difference between the two compressional curves - note the interval near the top f the log where the curves separate and the image log gets "shaky", indicating stress anisotropy. Fractures are indicated where the high amplitude (red colour on image log) disappears.

Full wave, array, and dipole sonic log presentations vary widely, depending on age, service company, and intended use.

Acoustic anisotropy coefficient is defined as:
      1: Kani = 0.5 * (Vmax - Vmin) / (Vmax + Vmin)

  Kani = anisotropy coefficient (fractional)
  Vmin = minimum acoustic (seismic) velocity (m/sec or ft/sec)
  Vmax = maximum acoustic (seismic) velocity (m/sec or ft/sec)

Equation 1 can be rewritten in log analysis terms as:
      2: Kani = 0.5 * (DTCmax - DTCmin) / (DTCmax + DTCmin)

Because of tool rotation, the log curves that represents the maximum and minimum values trade places, so the best solution is to take the absolute value of the difference between the two sonic log curves in the numerator. Some people multiply the anisotropy coefficient by 100 and display it as a percentage. Typical values range from zero for no anisotropy to as much as 25% in highly stressed regions.

An anisotropy coefficient based on resistivity values is also generated from well logs, but it has nothing to do with stress assessments. In this case it refers to the differences between vertical and horizontal resistivity in laminated rocks.:
      3: AnisRatio = RESvert / REShoriz
      4: AnisCoef = AnisRatio ^ 0.5

The resistivity ratio as defined here is nearly always greater than 1.0, and some literature uses the inverse of these terms, maintaining the same nomenclature..

Another important capability is the measurement of compressional and shear travel time values through casing, a formation evaluation method not usually available from conventional sonic logs. The compressional wave is only visible in holes where casing is well bonded to a full cement sheath. The shear and Stoneley waves are visible even if there is poor cement bond, but the annulus must be full of cement.

In addition, the tool can provide all standard measurements of the existing open hole sonic tools including short and long spaced BHCS logs and cement bond logs. Again the dipole tool works better than earlier array sonic logs.


Sonic Log Uncompensated Type (SL)
Curves Units Abbreviations
sonic travel time usec/ft or /m DELT or DTC
* gamma ray API GR
* caliper in or mm CAL
* sonic amplitude mv AMP
* variable density waveform usec VDL
* wave-form photographs usec WVE
* integrated travel time msec INT
* spontaneous potential mv SP
* porosity from sonic % or frac PHIS
* formation factor from sonic frac FS
Borehole Compensated Sonic Log (BHCS)
Curves Units Abbreviations
sonic travel time usec/ft or /m DELT or DTC
* gamma ray API GR
* caliper in or mm CAL
* sonic amplitude mv AMP
* variable density waveform usec VDL
* wave-form photographs usec WVE
* integrated travel time msec INT
* spontaneous potential mv SP
* porosity from sonic % or frac PHIS
* formation factor from sonic frac FS
Array Sonic Log (xxx)
Curves Units Abbreviations
sonic travel time compressional usec/ft or /m DT4P or DTC
sonic travel time shear usec/ft or /m DTS
sonic travel time Stoneley usec/ft or /m DTST
sonic travel time BHCS usec/ft or /m DTC or DELT
sonic travel time 8 inch usec/ft or /m DTC or DELT
* gamma ray API GR
* caliper in or mm CAL
* sonic amplitude compressional mv ACMP
* sonic amplitude shear mv ASHR
* sonic amplitude Stoneley mv ASTN
* integrated travel time msec INT
* variable density wavetrain usec VDL
* wave-form photographs usec WVE
* spontaneous potential mv SP
* porosity from sonic % or frac PHIS
* formation factor from sonic frac FS
Dipole Shear Imaging Log (DSI)
Curves Units Abbreviations
sonic travel time compressional usec/ft or /m DT4P or DTC
sonic travel time shear usec/ft or /m DTS
sonic travel time Stoneley usec/ft or /m DTST
sonic travel time BHCS usec/ft or /m DELT or DTC
* gamma ray API GR
* caliper in or mm CAL
* sonic amplitude compressional mv ACMP
* sonic amplitude shear mv ASHR
* sonic amplitude Stoneley mv ASTN
* integrated travel time msec INT
* variable density wavetrain usec VDL
* wave-form photographs usec WVE
* spontaneous potential mv SP
* porosity from sonic % or frac PHIS
* formation factor from sonic frac FS
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