Category Archives: Technology

Geochemical Logging Tool (GLT*)

Geochemical Logging Tool (GLT*)

Description
glt

Figure 1. Schematic of the GLT tool

The Geochemical Logging Tool (GLT) used three separate modes of gamma-ray spectroscopy to obtain measurements of most of the major oxides that make up sedimentary and igneous rocks. Initial measurements provided estimates of Si, Al, Fe, Ca, K, U and Th (together with H and Cl). Estimates of Ti, S and Gd were obtained later with further processing. The GLT provided gross geochemical information about the formation which was particularly useful when combined with other logs. The data could be used directly for the characterizationof geological sequences and phenomena, and were excellent for geotechnical zoning. However, due to its relatively low measurement precision (see the Environmental Effect section below), the GLT was best employed in environments where thereis a marked variation in the geochemistry of the rocks.

The GLT consisted of four components. At the top was a Natural Gamma Ray Tool (NGT), which measured the abundance of K, U, and Th from the natural gamma radiation given out by these elements. A sodium iodide detector was used for the measurement and also provided a spectrum of the background radiation, which was required for subsequent processing. Data were collected as the tool string was pulled up the borehole so that natural gamma-ray measurements were made before the formation was activated by the neutron and gamma spectroscopy tools below the NGT.

Beneath the NGT was a Compensated Neutron Porosity Tool  (CNTG), which in the GLT was used solely as a carrier for a Californium (252Cf) source. Californium was used instead of the conventional AmBe source because its spectrum has a lower energy (2 MeV instead of 4.5 MeV), thus reducing the number of fast neutron reactions that could interfere with measurements taken by the tools below. The source in the CNTG caused the neutron activation of Al, in which the natural isotope 27Al absorbed thermal neutrons and produced the isotope 28Al, which decays with a half life of 2.24 minutes and emits 1.78 MeV gamma rays.

Next was the aluminum activation clay tool (AACT), which was essentially an NGT with a modified spectrometer (7 windows instead of 5) to allow a more detailed analysis of the spectrum. The aluminum activation clay tool measured the gamma spectrum of the activated formation and the Al component was determined by subtracting the input from the natural gamma ray tool spectrum. There was often some spectral interference in the aluminum measurement from silicon, which was corrected during the land-based processing.

Finally, a gamma ray spectrometry tool (GST) was located at the bottom of the string. A boron exclusion sleeve surrounded the GST and increased the signal-to-noise ratio by shielding the path of fast neutrons from borehole fluid and reducing the number of capture reactions in the borehole itself, thus counteracting the effects of chlorine and water present in the borehole. The sleeve also reduced the interference of iron from the tool housing. The GST used a “minitron” tritium source to bombard the formation with pulsed 14 MeV neutrons. Through scattering reactions with the atoms in the formation, the neutrons progressively lose energy until they reach a thermal energy at which they can be captured by elemental nuclei in the rock. When this occurs the nucleus emits a gamma ray at a unique energy, characteristic for each element. The emitted gamma rays were measured by a spectrometer consisting of a sodium iodide detector and a 256-channel analyzer. During logging, the gamma ray spectrometry tool provided estimates of Si, Fe, Ca, S, Cl and H. In ODP boreholes the Cl and H related virtually entirely to the sea water in the borehole. Later land-based processing permitted the removal of Cl and H from the spectra, and the additional extraction of estimates for Ti and Gd.

The GST could operate in two timing modes: inelastic, which mainly measured the neutron reactions in the high energy range; and capture-tau mode, which employed prompt neutron capture reactions to measure elemental concentrations. This page describes how the gamma ray spectrometry tool functioned in capture-tau mode, which is how it was normally used in the Ocean Drilling Program.

The elements measured by the GLT account for the bulk of the chemistry of most common rocks; the only significant elements not measured were Na, Mg and possibly Mn. Under favorable circumstances, an estimate of these missing elements could be obtained by comparing a calculation of the photoelectric factor (Pe) from the elements measured above, with the direct measurement of Pe made by the Hostile Environment Lithodensity Tool (HLDS). The difference in these Pe values is, within limits of error, due to the unmeasured elements, and may be recast as either Na or Mg, or some combination, where a fixed ratio of the elements has to be assumed.

The GLT was run for the first time on ODP Leg 118. (Before then, only the GST component was run.) It was last deployed on ODP Leg 185 in 1999.


Applications

Lithology
glt_fig1 In basement, variations in elemental concentrations will help delineate flow boundaries and characterize alteration vein-filling. In sedimentary environments, where there is a reasonable chemical variation in the rocks, GLT data can be used as an effective indicator of changes in the lithostratigraphy.

Cyclically interbedded lithologies can be identified and analyzed using geochemical logging, and changes in the provenance of sediments can be shown. For example, the FeO, SiO2 andCaCO3 results from ODP Hole 950A on the Madeira abyssal plain show distinct downhole alternations (see Figure 2) . Horizons which are generally rich in FeO, rich in SiO2 and poor in CaCO3 show the position of clay-rich organic and volcanic distal turbidites, sourced from volcanic  islands and the African margin, to the east of the drill-site. Horizons generally poor in FeO, poor in SiO2, and rich in CaCO3 show the position of calc-turbidites, sourced from a chain of seamounts to the west of the plain.

The ratio of certain elemental yields can also be used to emphasize fluctuations or distinct marker horizons in the stratigraphy. For example, elemental yield ratios were used to analyze data from ODP Hole 999B, drilled beneath the Caribbean Sea. The lithology (Si/(Si + Ca)), iron (Fe/(Si + Ca)) and porosity (H/(Si + Ca)) indicator ratios all help to highlight the position of tephra horizons within the formation (see Figure 3).
glt_fig2
Geochemistry
Downhole fluctuations in the elemental yields reflect gross variations in geochemistry, which can be used to help categorize the formation. The GLT results from Hole 735B, logged during Leg 118, show a good example of this. This hole penetrated basement of the Southwest Indian Ridge, which between 50-400 mbsf can be subdivided into four distinct units (see Figure 4). The geochemical data clearly delineate Unit 4, which is a Fe-Ti oxide-rich gabbro. Generally low and uniform FeO and TiO2 values occur in Unit 5, which is a relatively uniform olivine gabbro.
glt_fig3

Quantitative mineralogy and lithology The oxide data, in combination with data from other logs if appropriate, can be inverted to estimate the proportions of the main minerals in the rock. This information, which can be displayed as mineralogical logs, can often be used to derive other physical properties of the formation, such as magnetic susceptibility or cation exchange capacity (CEC).


Environmental Effects
During data acquisition the signal-to-noise ratio of the gamma ray measurement could be affected by the following:
Logging speed: This is normally between 400 and 600 ft/hr, with measurements being made every six inches. The slower the logging speed the greater the measurement precision.

Borehole fluids and porosity: Due to the large capture cross-section of chlorine and hydrogen more than half of the gamma ray spectrometry tool signal may come from the borehole fluid (normally seawater). This can adversely affect the measurement precision of the other element yields. High porosity rocks can have a similar affect on precision, and it is recommended that the GLT only be used in rocks with less than 40% porosity.

Hole size: This is of particular importance as oversized holes cause an increase in the signal derived from the borehole fluids, and a decrease in the signal from theformation. The interpretation of geochemical logs should, therefore, always be undertaken in conjunction with caliper logs. Because the aluminum activation clay tool has a low activation energy (2 MeV), aluminum is measured in a much smaller volume of rock than those elements measured by the gamma spectroscopy tool. As a result, with increasing hole size, the aluminum signal decreases rapidly and may reach background levels, whereas the gamma spectroscopy tool elements can still be measured. This problem is compounded by the oxide closure procedure, which forces the major oxides to a constant sum (usually 100%).

Temperature: Temperature effects can significantly reduce the efficiency of the NaI detector in the gamma ray spectrometry tool, with higher temperatures resulting in a poor signal-to-noise ratio and decreased resolution. Poor resolution will result in gamma-ray peaks appearing in the wrong window and lead to incorrect identification of the element represented. It is recommended that the GLT not be used in temperatures greater than 150°C.

The quality of the data could also be reduced during processing. This could occur due to errors in the spectral inversion of the raw data, inaccuracies in the oxide closure model caused by the presence of unmeasured elements, and incorrect oxide factor assumptions. In the ODP, shipboard data (particularly petrographic, chemical and diffraction) could often be used to minimize these errors.

One limitation of the GLT was its relatively low spatial resolution. The volume sampled by the GLT approximated to a sphere, with a radius varying from around 0.3-1.0 m, depending on lithology, porosity, composition of the pore fluids and the elemental spectra being determined. At each measurement point (every 15 cm) a number of these spherical samples were averaged. The raw data from the GLT had, therefore, already undergone a certain amount of smoothing. This accentuated the shoulder effect on the logs, which tended to smooth the log responses over sharp lithological boundaries.Comparisons between GLT-derived oxide estimates and similar data obtained from conventional geochemical analyses (e.g., XRF)on core samples should be treated with extreme caution. The two techniques measure substantially different volumes of rock. Furthermore, it is always difficult to precisely match the depths of the core samples with those of the log values, especially when core recovery is low.


Log Presentation
Following data acquisition, the elemental concentrations measured by the GLT were expressed as decimal fractions and the elements were normalized to unity. Further processing, sometimes referred to as the “oxide closure procedure,” converted the major elements (Si, Al, Ca, Fe, S, Ti, K, Cl and H) to weight percent oxides. The trace elements (U, Th and Gd) were expressed in parts per million. Post-cruise processing also allowed the expected errors on the GLT data to be calculated (see Figure 2).


Tool Specifications
Temperature rating: 300°F (150°C)
Pressure rating: 20 kpsi  (138 MPa)
Diameter: 3.875 in  (9.2 cm)
Length: 69 ft (21 m)
Sampling interval: 6 in (15.24 cm)
Maximum logging speed: 600 ft/hr  (182.88 m/hr)


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Enhanced Digital Telemetry Cartridge (EDTC-B*)

Enhanced Digital Telemetry Cartridge (EDTC-B*)

Description
The Enhanced Digital Telemetry Cartridge (EDTC-B*) is a downhole tool that combines two commonly run sensors with a high-speed telemetry downhole modem that can be used in high-pressure and high-temperature environments. The primary function is to provide high-speed (over 1 Mbps) communications between the wireline tools downhole and the acquisition system at surface. Additionally, it includes a scintillation gamma ray detector that provides a simple total GR count in API units that is used for correlation between logging runs. Therefore, the use of the EDTC eliminates the need for the spectral gamma ray tool (HNGS), thus reducing the length of the string.
Finally, the EDTC includes a single-axis accelerometer to provide the “z-axis” (i.e., along the longitudinal axis of the tool string) acceleration. This measurement can be used to observe downhole tool motion and apply speed corrections during the post-logging data processing, if desired. If a wireline heave compensator is used, the vertical (z-axis) acceleration data can be used to evaluate the heave compensator performance. The auxiliary measurements (GR and Az) provided by the EDTC cannot be used unless the EDTC is the downhole modem (telemetry module) for the entire string, so it cannot be run strictly for those measurements in combination with a different telemetry tool.
If the EDTC is deployed as the telemetry cartridge, it is still quite possible to use alternate sensors such as the HNGS and GPIT to provide the GR and Az measurements without any conflict. By combining telemetry, basic gamma ray, and a vertical accelerometer, the EDTC provides the greatest telemetry bandwidth currently available in a shorter package than would otherwise be necessary to acquire the same basic measurements.


Main Outputs
ECGR: Environmentally Corrected Gamma Ray
EHGR: High Resolution Corrected Gamma Ray
GR: Gamma Ray
HGR: High Resolution Gamma Ray
MTEM: Mud temperature


Deployment Notes
The EDTC-B is typically run at the top of the tool string. In most cases, the more accurate HNGS (spectral gamma ray tool) is run as well.


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General Purpose Inclinometry Tool (GPIT*)

General Purpose Inclinometry Tool (GPIT*)

Description
gpit_figThe GPIT* General-Purpose Inclinometry Tool provides inclinometer measurements. Tool orientation is defined by three parameters: tool deviation, tool azimuth, and relative bearing. The GPIT tool uses both a three-axis inclinometer and a three-axis magnetometer to make measurements for determining these parameters.

The basic principle of downhole inclinometer measurements is to define accurately the tool system axis with respect to the Earth’s gravity (G) and magnetic field (F). Because both vectors are well defined within the Earth system, a relation can be established between the tool and Earth systems. The magnetometer determines Fx, Fy, and Fz, and the inclinometer determines Ax, Ay, and Az for the acceleration due to G. The MAXIS Multitask Acquisition and Imaging System computes deviation, azimuth, and relative bearing from these values.


Applications
  • Borehole azimuth deviation and relative bearing.
  • Orientation of UBI images.
  • GPIT data can be used for paleomagnetic studies of oceanic basement. In highly magnetized formations the three-axis magnetometer records the magnetic anomalies caused by the magnetization of the rocks surrounding the borehole.


Environmental Effects
When the GPIT tool is used in an open wellbore, the tools above and below it must have nonmagnetic housings. In a cased hole the tool can be used only for deviation and relative bearing measurements.


Tool Specifications
Temperature rating: 350° F (177° C)
Pressure rating: 20 kpsi (138 MPa)
Diameter: 3.625 in (9.2 cm)
Length: 4 ft (1.22 m)
Weight: 55 lbs (25 kg) 


Measurement Specifications
Range: 0° – 360°
Vertical Resolution: 6 in. (15.24 cm)
Logging speed: 3600 ft/hr
Accuracy: ±2% (Azimuth and deviation)


Main Outputs
FX: Magnetic field on X Axis (oersted)
FY: Magnetic field on Y Axis (oersted)
FZ: Magnetic field on Z Axis (oersted)
FINC: Magnetic field inclination (degrees)
FNOR: Magnetic field total moment (oersted)
AX: Acceleration X Axis (ft/s2)
AY: Acceleration Y Axis (ft/s2)
AZ: Acceleration Z Axis (ft/s2)


Deployment Notes The GPIT is typically run with the DSI, FMS, HNGS and UBI.


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Dipole Sonic Imager Tool (DSI-2*)

Dipole Sonic Imager Tool (DSI-2*)

Description
The Dipole Sonic Imager Tool (DSI-2) combines high-speed telemetry with simultaneous, 12-bit dynamic range digitization of an eight-receiver array. The sonde incorporates both monopole and crossed-dipole transmitters with an eight-station array of electronically configurable hydrophones for monopole and dipole reception. Combining new dipole-based technology with the latest monopole developments into one system provides the best method available today for obtaining dsi_schematicborehole compressional, shear and Stoneley slownesses (slowness is the reciprocal of velocity and corresponds to the interval transit time measured by standard sonic tools).

The transmitter section of the DSI contains three transmitter elements: one omnidirectional monopole ceramic transducer and two unidirectional wide-band electrodynamic dipole transducers oriented perpendicular to each other. Wide-band transducers are preferable to a single narrow-band source because they allow examination of the entire frequency spectrum without phase-matching problems at their resonant frequencies and are not subject to reduced output because of aging. A low-frequency pulse drives the monopole transducer for Stoneley wave excitation, and a high-frequency pulse drives it for compressional and shear measurements. A low-frequency pulse drives each dipole transducer for the creation of shear waves. In addition, a new low-frequency source option provides excitation below 1 kHz for extremely large holes and for very slow formations and shear waves.

The receiver section contains eight receiver stations spaced 6 in. apart and spanning 3.5 ft. Each station contains two hydrophone pairs: one oriented in line with the upper dipole transmitter and the other in line with the lower dipole transmitter. The outputs from each pair are differenced for dipole reception and summed for monopole reception. Receivers are carefully matched during manufacture and the receiver array provides more spatial samples of the propagating wavefield for full waveform analysis. The arrangement of the transmitters and receivers allows measurement of wave components propagating deeper into the formation.

The acquisition cartridge contains the circuitry to perform automatic gain control, digitize eight separate waveforms simultaneously, stack these waveforms from more than one firing and then transmit the signals uphole. Threshold detectors for recording amplitude threshold crossing times for each waveform are also present. These are for compressional first-motion detection and allow derivation of compressional slowness in a manner similar to the analog threshold detection scheme used in conventional sonic tools.

Dipole technology allows borehole shear measurements to be made in “soft” rock as well as “hard” rock formations. Limited by borehole physics, monopole tools can detect only shear velocities that are faster than the borehole fluid velocity — or in hard rocks only. Dipole tools overcome this fluid velocity barrier.

Tool Operation Modes

The DSI tool has several data acquisition operating modes, any of which may be combined to acquire digitized waveforms over each 6-in. logging interval. For waveforms, eight channels are digitized simultaneously with a 12-bit dynamic range. Upper and lower dipole modes
Eight dipole waveforms from firings of either of the dipole transmitters — sampling every 40 microsec, 512 samples/waveform.

Cross-dipole mode
Standard acquisition of 32 total waveforms, in-line and cross-line from both transmitters — sampling every 40 microsec, 256 samples/waveform.

Stoneley mode
Eight monopole waveforms from firings of the monopole transmitter driven with a low-frequency pulse — sampling every 40 microsec, 512 samples/waveform.

P&S Monopole mode
Eight monopole waveforms from firings of the monopole transmitter driven with a high-frequency pulse — sampling every 10 microsec, 512 samples/waveform.

First-motion mode
Eight sets of monopole threshold-crossing data from firings of the monopole transmitter driven with a high-frequency pulse — primarily for compressional first-arrival applications.

Features
  • New fast tool bus and data reduction techniques have allowed double the maximum logging speed in most instances.
  • A switchable power regulator has enabled a one-third reduction in power needs, resulting in broader combinability with other tools.
  • Additional human-interface engineering has improved field acquisition quality and efficiency.
  • A new low-frequency transmitter driver improves signal-to-noise ratio and allows successful logging of extremely slow formations and greatly enlarged holes.
  • Improved waveform processing techniques have greatly improved vertical resolution.
  • New answer products utilize Stoneley slowness to evaluate fractures and indicate permeability.
In addition to the new dipole features, acquisition of the Stoneley wave velocity utilizes a low-frequency monopole energy pulse for highest-quality Stoneley measurements. Stoneley-derived permeability is useful for evaluating fractures as well as investigating deeply into the formation.

A new technique for detecting compressional wave arrival–digital first-motion detection (DFMD)–provides measurements that are compatible with previous sonic logs, in addition to a 6-in (15 cm) vertical resolution compressional sonic.

Processing with the MAXIS wellsite unit displays a full wave and its component characteristics. Its high-speed array processor uses the slowness-time-coherence (STC) method to determine compressional, shear and Stoneley slowness values. A choice of band-pass filters permits utilization of the optimum frequency range within a mode. The process reliably provides unambiguous transit times even in difficult borehole conditions. The resulting values are useful inputs for mechanical properties, formation evaluation and seismic applications.

Details on acoustic wave propagation can be found here.


Depth of Investigation/Eccentering Effects

Depths of investigation for sonic devices depend on the formation type, shear and compressional slowness, the transmitter-to-receiver spacing, wavelength of the wave considered and whether it is a head wave or a guided wave, the source frequency and signal types.

Frequency determines the wavelength that drives the depth of investigation of the measurement.

Typical sonic wavelengths at different frequencies and slownesses are shown in the “Additional Specifications” table. Low frequency penetrates deeper into the formation and helps read beyond altered zones.

Numerical simulations verified by measurements from scale models show that when eccentering is small compared to the borehole radius, there is little change in the character of the dipole waveforms or in the STC-processed slowness values. Large eccentering, on the order of 2 to 4 in (5-10 cm) in a 12-in (31 cm) borehole, increases the flexural wave amplitude relative to the compressional. For the DSI-2 tool, the variation in the shear slowness estimate is ± 2 percent over the normal slowness range.


Log Presentation

Slowness or velocities can be plotted alongside resistivity, density, or image data. dsiplot

Tool Specifications
Temperature rating: 350°F (175°C)
Pressure rating: 20 kpsi (138 MPa)
Diameter: 3.375 in (8.57 cm)
Length: 51 ft (15.5 m)
Weight: 900 lbs (408.6 Kg)
Sampling interval: 10 and 40 µs
Logging speed:
        Single mode 3,600 ft/hr (1,097 m/hr)
        All six modes simultaneously, no 6-in slowness 1,000 ft/hr (305 m/hr)
        All six modes simultaneously, with 6-in slowness 900 ft/hr (274 m/hr)
Acoustic bandwidth:
Dipole and Stoneley: 80 Hz to 5 kHz
High-frequency Monopole 8 to 30 kHz


Measurement Specifications
Vertical resolution: 3.5 ft (1 m) for 6-in (15.24 cm)
Depth of investigation: 9 in (23 cm)
Accuracy: 2 µs/ft (6.6 µs/m)
Sampling rate: 0.5 ft (15,24 cm)


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Dual Laterolog (DLL*)

Dual Laterolog (DLL*)

Description
The Dual Laterolog (DLL) provided two resistivity measurements with different depths of investigation into the formation: deep (LLd) and shallow (LLs). In both devices, a current beam 2 ft-thick (A0) was forced horizontally into the formation by using focusing (also called bucking) currents (A1– A2, A’1-A’2); monitoring electrodes (M1, M2, M’1, M’2) were part of a loop that adjusted the focusing currents so that no current flowed in the borehole between the two electrodes. For the deep measurement both measure and focusing currents returned to a remote electrode on the surface; thus, the depth of investigation was greatly improved and the effect of borehole conductivity and of adjacent formations was reddlluced. In the shallow laterolog, the return electrodes that measured the bucking currents were located on the sonde and the current sheet thus retained focus over a shorter distance than the deep laterolog.

The Dual Laterolog had a response range of 0.2 to 40,000 Ω.m, whereas the Phasor Dual Induction Tool (DIT) had a range of 0.2 to 2,000 Ω.m. The DLL was useful for igneous environments (e.g., oceanic basalts and gabbros) because the resistivities can be higher than the upper limit of what the DIT can measure. However, in upper crustal environments (seismic Layers 2A and 2B), the resistivities are usually low enough that the DIT can be used. This was the case in data from, for example, ODP Legs 104 and 152 as well as Hole 395A.

The depth of investigation of the laterolog depended on the resistivity of the rock and on the resistivity contrast between the zone invaded by the drilling fluid and the virgin (uninvaded) zone. The vertical resolution of both LLd and LLs depended on the geometry defined by the focusing electrodes: this is about 2 ft (61 cm).

The DLL was first deployed during DSDP in 1977 and was last used on IODP Expedition 312 in 2005.


Applications

Porosity
Because of the inverse relationship between resistivity and porosity, the dual laterolog could be used to compute the porosity of the rock from Archie’s equation if the sediments/rocks do not contain any clay or if the contribution of surface conduction to the signal is negligible.

Fracture porosity
This could be estimated from the separation between the deep and shallow measurements based on the observation that the former was sensitive to the presence of horizontal conductive features only, while the latter responded to both horizontal and vertical conductive structures.


Environmental Effects
For the LLD, the borehole effect was small for hole diameters up to 16 in, while the LLS provided good readings in holes not exceeding 12 in. Corrections were available for holes up to 20 in (25 cm) in diameter.


Log Presentation
The LLD and LLS curves were usually displayed on a resistivity logarithmic scale, along with the gamma ray log. dllplot
Tool Specifications
Temperature rating: 350° F (175° C)
Pressure rating: 20 kpsi (138 MPa)
Diameter: 3.625 in (9.21 cm)
Length: 30.6 ft (9.35 m)
Weight: 222 lbs (100.8 kg)
Sampling interval: 6 in (15.24 cm)
Max. logging speed: 10,000 ft/hr (3,048 m/hr)


Measurement Specifications
Range: 0.2-40,000 Ω.m
Depth of investigation: See discussion in “Description” section
Vertical resolution: 2.5 ft (76 cm)


Major Outputs
LLD: Deep laterolog (Ω.m)
LLS: Shallow laterolog (Ω.m)


Deployment Notes
The DLL was usually run in combination with a Gamma Ray Tool (GR, SGT, NGT, HNGS).


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Logging-While-Drilling—Compensated Dual Resistivity Tool (LWD-CDR*)

Logging-While-Drilling—Compensated Dual Resistivity Tool (LWD-CDR*)

Description
lwd_pic The LWD-CDR was an electromagnetic propagation and spectral gamma ray tool built into a drill collar. It had many similarities to dual induction tools: it responded to conductivity rather than to resistivity, operated in water- or oil-base muds, and provided two depths of investigation. It had better vertical resolution, but a shallower depth of investigation, than dual induction tools.
The tool broadcasted a 2-Mhz electromagnetic wave and measured the phase shift and the attenuation of the wave between two receivers. These quantities were transformed into two independent resistivities that provided the two depths of investigation. The phase shift was transformed into a shallow resistivity (PSR); the attenuation was transformed into a deep resistivity (ATR).
The LWD-CDR had upper and lower transmitters that fired alternately. The average of these phase shifts and attenuations for the upward and downward propagating waves provided a measurement with borehole compensation similar in principle to that of the Borehole-Compensated Sonic Tool (BHC). Borehole compensation reduces borehole effects in rugose holes, improves the vertical response, increases measurement accuracy and provides quality control for the log. An electrical hole diameter was computed from the CDR data and was used as an input to hole size corrections.
cdr
Detection of 3 in. (7.5 cm) beds was possible with the CDR tool. However, because of shoulder bed effects, Rps and Rad will read too low in a thin, resistive bed with conductive shoulder beds, and a small correction for bed thickness was required to obtain true  resistivity, Rt. A major advantage of the CDR tool was its ability to measure Rt in thin beds before invasion occurs. Once thin beds are deeply invaded, there is no reliable method for obtaining true resistivity.
The LWD-CDR was deployed during the Ocean Drilling Program from 1994—2000. It has been superceded by the LWD-arcVISION.


Applications – Resistivity Measurements
Porosity: In sediments that do not contain clay or other conductive minerals, the relationship between resistivity and porosity has been quantified by Archie’s Law. Archie’s Law relates the resistivity to the inverse power of porosity. This relationship has also been used to estimate apparent porosity in oceanic basalts.

Density and velocity reconstruction: Archie’s equation has been used effectively to create “pseudodensity” and/or “pseudovelocity” logs from porosity over intervals where no such logs were recorded or were totally unreliable. In some instances velocities derived from resistivity logs can be used to depth-tie seismic reflectors.

Lithologic boundary definition and textural changes: Resistivity, along with acoustic and velocity logs, is a very valuable tool  in defining lithologic boundaries over intervals of poor core recovery. In a particular example, the decrease in resistivity towards the top of a carbonate unit, coupled with a decrease in velocity, allowed one to interpret this unit as a fining-upward sequence in mostly carbonatic sediments. Similar saw-toothpatterns in the resistivity response can also be observed in oceanic basalt units where they are related to porosity changes towards the top of each unit.


Applications – Natural Gamma Ray Measurements
Clay typing: Potassium and thorium are the primary radioactive elements present in clays; because the result is sometimes ambiguous, itcan help combining these curves or the ratios of the  radioactive elements with the photoelectric effect from the lithodensity tool.

Mineralogy: Carbonates usually display a low gamma ray signature;an increase of potassium can be related to an algal origin or to the presence of glauconite, while the presence of uranium is often associated with organic matter.

Ash layer detection: Thorium is frequently found in ash layers. The ratio of Th/U can also help detect these ash layers.


Environmental Effects
The CDR tool provided a set of corrections for different environmental effects. These included corrections for adjacent formations, borehole signal, and invasion. Differences in the temperature of drilling fluid compared to undisturbed formation temperatures can also generate environmental effects, as conductivity in ionic fluids such as seawater is strongly temperature dependent.


Log Presentation
Attenuation Resistivity (ATR) and Phase Shift Resistivity(PSR) are usually plotted in Ω.m on a logarithmic scale along with gamma ray (GR) log in API units. A full display of the Natural Gamma Spectroscopy data with SGR(total gamma ray), CGR (computed gamma ray — SGR minus Uranium component), and THOR (in ppm), URAN (in ppm), and POTA (in wet wt%) was usually provided separately.


Tool Specifications
Temperature rating: -13° to 300° F (-25° to 150° C)
Pressure rating: 18 kpsi (124 MPa)
Length: 22 ft (6.7 m), with savers
Weight: 2000 lbf (907 kg)
Maximum flow rate; 600 gal/min
Maximum weight on bit: F = 63,000,000/L² lbm (where L is the distance between stabilizers in feet)
Available collar sizes: 6.75 in, 8.25 in (17.1 cm, 21 cm)
Available stabilizers: 8.50 in, 9.75 in (21.6 cm, 24.8 cm)


Main Outputs
GR Gamma ray (API Units)
SGR Total gamma rRay (API units)
CGR Computed gamma ray (API units)
POTA Potassium (wet wt. %)
THOR Thorium (ppm)
URAN Uranium (ppm)
ATR Attenuation resistivity (deep; Ω.m)
PSR Phase Shift resistivity (shallow; Ω.m)
GTIM CDR gamma ray time after Bit (sec)
RTIM CDR resistivity time after Bit (hr)

Deployment Procedures
lwd_deployment lwd_deploy *®trademark of Schlumberger

Formation MicroScanner (FMS*)

Formation MicroScanner (FMS*)

Description
fmspad

Sixteen-electrode arrangement for the four-pad tool.

The Formation MicroScanner sonde (FMS) consists of four orthogonal imaging pads each containing 16 microelectrodes which are in direct contact with the borehole wall during the recording. The button current intensity is sampled every 0.1 in (2.5 mm). The tool works by emitting a focused current from the four pads into the formation. The current intensity variations are measured by the array of buttons on each of the pads.

Processing transforms the current intensity measurements, which reflect the microresistivity variations of the formation, into high resolution gray or color images of variable intensity. Black and white (darkest or lightest color) indicate low and high microresistivity, respectively. The tool also includes a General Purpose Inclinometry Cartridge (GPIT) which provides accelerometer and magnetometer data in order to allow one to define the tool position and spatial orientation of the data.

In smooth boreholes with very homogeneous bedding the depth of investigation is about 10 in (25 cm). The vertical resolution is 0.2 in (5 mm).


Applications
  • Mapping of bedding planes, fractures, faults, foliations, and other formation structures and dip determination.
  • Detailed correlation of coring and logging depths.
  • Precise positioning of core sections where core recovery is less than 100%.
  • Analysis of depositional environments.


Log Presentation
FMS images can be plotted with identical vertical and horizontal scales to see features without exaggeration. However, due to physical constraints, different vertical and horizontal scales are commonly used. The images are displayed on an oriented plot, also called an azimuthal plot, because the images are positioned according to their orientation in the borehole with N in the center and S on both edges. Images from two passes of the tool can be merged and plotted together. The calipers or other curves can be plotted alongside the images as well. With an additional processing step, dipmeter calculations can be made. Standard dipmeter plots consist of borehole drift, calipers, dip angle and direction (tadpoles), azimuth frequency plots, and pad traces.
fmslog4 fmstadpole4

Turbidite sequences are imaged here by the FMS data. Red sine waves on the images trace bedding planes.The corresponding “tadpole” plot shows the average dip is roughly 40 degrees to the west. Interpretive work of the FMS data can be performed either on the ship or onshore with the GeoFrame software.


Tool Specifications
Temperature rating: 350° F (175° C)
Pressure rating: 20 kpsi (138 MPa)
Diameter: 3.625 in (9.2 cm)
Length: 25.3 ft (7.72 m)
Weight: 537 lbs (243.8 Kg)
Sampling interval: 0.1 in (2.5 mm)
Maximum logging speed: 1,800 ft/hr (549 m/hr)


Measurement Specifications
Vertical resolution: 0.2 in (5 mm)
Depth of investigation: 10 in (25 cm)


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Borehole Geometry Tool Kit (BGKT*)

Borehole Geometry Tool Kit (BGKT*)

Description
bgkt
The Borehole Geometry Tool Kit (Schlumberger Seismos Prakla VSP Tool) was a three-component VSP tool that was used for many years in the petroleum exploration industry. At the time of its deployment in ODP, it was the slimmest available Schlumberger 3-axis VSP tool.
Each of the BGKT’s three components contained eight 10 Hz geophones. The preamplifier was 20 or 40 dB, selected at the surface.
The BGKT was deployed during ODP Leg 176.


Tool Specifications
Temperature rating: 500° F (260&deg& C)
Pressure rating:  23 psi (158.5 MPa)
Diameter:  3.75 in (95 mm)
Length: 10.5 ft (3.2 m)
Weight: 253 lb (115 kg)
Max. borehole diameter 16 in (40 cm)
Signal conditioning: Eight 10 Hz geophones/axis with preamplifier (20/40 dB, selected at surface)
Other:  Monolithic tool, no stand-offs

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Compensated Neutron Dual Porosity Tool (CNT-G*)

Compensated Neutron Dual Porosity Tool (CNT-G*)

Description
The CNT-G tool employed a chemical source (Am-Be) to bombard the borehole and the formation with fast neutrons (4.5 MeV) and two pairs of sensors to detect the number of neutrons (count rates) in the epithermal (100 eV – 0.1 eV) and thermal energy range (<0.025 eV). In the scattering process the neutrons interacted elastically with the atoms in the formation, were slowed down, and lost part of their kinetic energy with each collision; upon reaching the thermal energy level, they were absorbed by the surrounding nuclei. The amount of energy lost by the neutrons depended on the relative mass of the nuclei with which they interacted Because the greatest energy loss occurs during the collision with hydrogen atoms – which have a mass almost equal to that of neutrons – the slowing down and capture processes were mainly controlled by the hydrogen concentration in the formation. By taking the ratio of count rates at each pair of detector, a measurement of the porosity of the formation — compensated for the borehole parameters — was provided.
The response at the thermal detectors could be greatly affected by elements with a large thermal neutron capture cross section, such as chlorine, boron, gadolinium, and samarium; these are usually present in very small quantities in the borehole fluid or in clay or alteration minerals, yet they can cause the porosity of the formation to be overestimated. The epithermal detectors, instead, were less sensitive to these neutron absorbers and provided a more reliable measurement of the true porosity of the formation over clay-rich intervals. Because the epithermal neutron count rate is about one order of magnitude less than that for the thermal neutrons, the detectors were placed closer to the source in order to improve statistical variations.
The CNT-G was deployed extensively during the Ocean Drilling Program.


Applications

Porosity
In reservoir engineering its importance is quite evident; in the study of the volcanic rocks that make up the upper oceanic crust, a good in-situ porosity measurement is most important to the correct understanding of the crustal structure: first, because it samples both the small-scale (microcrack, vesicle) porosity seen in the cores and the large-scale fractures not sampled by drilling; and second, because other properties such as density, seismic velocity, and permeability, depend strictly on porosity variations and on the geometry of the pore space. In the presence of clays or hydrous alteration minerals a correction is required to account for the presence of bound water.

Lithology
Because the hydrogen measured by the tool is present not only as free water but as bound water in clay minerals, the porosity curve, often combined with the density log, can be used to detect shaly intervals or minerals such as gypsum, which has a high hydrogen index due to its water crystallization. Conversely, the neutron curve can be used to identify anhydrite and salt layers (which are both characterized by low neutron readings and by high and low bulk density readings, respectively).


Environmental Effects
Eccentralization of the tool by a bow spring could be very helpful in obtaining reliable porosity measurements. The lack of contact of the tool with the borehole wall during the recording results in the attenuation of the formation signal by the borehole fluid and, in turn, the likely overestimation of the true porosity of the formation. In the majority of ODP holes, however, the CNT-G was run without an eccentralizer.
Hole size also affects the neutron log response: the formation signal, particularly for the epithermal count rates, tends to be masked by the borehole signal with increasing hole size.
In liquid-filled holes the influence of the borehole fluid depends on its salinity – chlorine is a strong absorber – and density: the addition of weighting additives such as barite will yield a lower porosity reading.
In the Ocean Drilling Program, the neutron tool was sometimes recorded through the drilling pipe and the bottom hole assembly. Because iron is a strong neutron absorber, the effect was an increased porosity reading, depending on the thickness of the pipes.


Log Presentation
The CNT-G provided an epithermal (ENPH) and thermal neutron porosity (NPHI) measurement. The porosity curves were presented either in decimal units or in percents along with the bulk density.


Tool Specifications
Temperature rating: 400° F (200° C)
Pressure rating: 20 kpsi (138 MPa)
Diameter rating: 3.375 in (8.6 cm; without bow spring eccentralizer)
Length: 7.25 ft (2.21 m)
Weight: 120 lbs (54 kg)
Sampling interval: 6 in (15.24 cm)


Measurement Specifications
Vertical resolution: 12 in (30.48 cm)
Depth of investigation: ~ 9 in (22.9 cm)
Accuracy:
0-20 pu: ±1 pu
30 pu: ±2 pu
45 pu: ±6 pu


Main Outputs
ENPH: Epithermal Neutron Porosity (pu)
TNPH (or NPHI): Thermal Neutron Porosity (pu)
CFEC: Corrected Far Epithermal Counts (cps)
CFTC: Corrected Far Thermal Counts (cps)
CNEC: Corrected Near Epithermal Counts (cps)
CNTC: Corrected Near Thermal Counts (cps)
ENRA: Epithermal Neutron Ratio
TNRA: Thermal Neutron Ratio


Deployment Notes The CNT-G was typically run in combination with the density and gamma ray tools.


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Compensated Neutron Log (CNL*)

Compensated Neutron Log (CNL*)

Description
The compensated neutron log tool (CNL) contained a 16-curie Am/Be radioactive source that bombarded the formation with fast neutrons and two detectors at different spacings from the source. The neutrons were slowed down through elastic collision with the formation nucleii and then captured, primarily by hydrogen atoms in the formation. The slowed neutrons deflected back to the tool were counted by detectors. The tool responded primarily to the hydrogen content of the formation because hydrogen has a mass close to that of the neutrons and thus is most efficient in the slowing process.
The measurements (ratios of far to near detector counts) were transformed to porosity units on the basis of laboratory calibrations. The 16-curie source produced neutrons at four times the rate of a standard nuclear source, greatly reducing statistical variation. The use of longer source-to-detector spacings increased the depth of the investigation.
The CNL was used during the Deep Sea Drilling Project.


Applications

Porosity
In reservoir engineering its importance is quite evident; in the study of the volcanic rocks that make up the upper oceanic crust, a good in-situ porosity measurement is most important to the correct understanding of the crustal structure: first, because it samples both the small-scale (microcrack, vesicle) porosity seen in the cores and the large-scale fractures not sampled by drilling; and second, because other properties such as density, seismic velocity, and permeability, depend strictly on porosity variations and on the geometry of the pore space. In the presence of clays or hydrous alteration minerals a correction is required to account for the presence of bound water.

Lithology
Because the hydrogen measured by the tool is present not only as free water but as bound water in clay minerals, the porosity curve, often combined with the density log, can be used to detect shaly intervals or minerals such as gypsum, which has a high hydrogen index due to its water crystallization. Conversely, the neutron curve can be used to identify anhydrite and salt layers (which are both characterized by low neutron readings and by high and low bulk density readings, respectively).


Environmental Effects
The tool was designed to minimize the effect of hole size. When run in combination with the FDC (formation Density Compensated Tool), the caliper measurement was used to apply an automatic correction for hole diameter. Other factors that might affect the porosity reading were temperature, salinity, lack of eccentralization (standoff) and type of drilling fluid.


Log Presentation
The CNL was recorded in linear porosity units (or %) for a particular matrix lithology (limestone, sandstone, dolomite, usually limestone). When a CNL was run in combination with another porosity log, both curves were recorded on the same porosity scale. This overlay-type presentation permitted visual qualitative interpretation of porosity and lithology or the presence of gas.


Main Outputs
NPHI: Neutron porosity (%)
NCNL: Near detector counts (cps)
FCNL: Far detector counts (cps)


Tool Specifications
Diameter: 3.375 in (8.6 cm)
Sampling interval: 6 in (15.24 cm)


Deployment Notes
The CNL was usually run in combination with the FDC or LDT tools.


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