WO1999035515A1 - Electromagnetic logging tool with reflector for directional sensing - Google Patents
Electromagnetic logging tool with reflector for directional sensing Download PDFInfo
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- WO1999035515A1 WO1999035515A1 PCT/US1999/000502 US9900502W WO9935515A1 WO 1999035515 A1 WO1999035515 A1 WO 1999035515A1 US 9900502 W US9900502 W US 9900502W WO 9935515 A1 WO9935515 A1 WO 9935515A1
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
- G01V3/26—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
- G01V3/28—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
Definitions
- the present invention relates to a logging tool used to search for underground mineral or fossil fuel deposits and, more particularly, to a method and apparatus for determining the electrical conductivity of formations proximate to a borehole.
- Electrical conductivity (or its inverse, resistivity) is an important property of a rock formation in geological surveys and prospecting for oil and gas because many minerals, and more particularly hydrocarbons, are less conductive than common sedimentary rocks. Thus a measure of the conductivity is often a guide to the presence and amount of oil or gas.
- Induction methods using coils to generate and sense time- varying electromagnetic fields are widely used in borehole geophysical surveys, or "logs", to determine the local rock properties including conductivity, dielectric permittivity, and magnetic permeability.
- arrays of such coils mounted coaxially with the borehole axis, and operating in the frequency range from 5KHz to 200KHz (typically about 20KHz) are used to sense the conductivity, while frequencies up to 200MHz may be used to determine dielectric permittivity.
- the magnetic properties, while valuable, are not commonly measured by these methods due to the difficulty of separating their effects from those of conductivity.
- This highly developed art has been extended to logging tools located in a drillstring and operative while drilling the borehole, thus saving the cost of removing the drill string from the well in order to perform a logging survey.
- This improvement has created a new application of the method called geosteering, wherein a real-time evaluation of the formation data acquired by logging while drilling may be used in conducting directional drilling operations.
- logs may be used to monitor a producing well that is not cased and to indicate the approach of water or gas boundaries (e.g. coning) during workover jobs.
- information about the location of the geological and fluid boundaries of a reservoir are very valuable in determining the total volume of hydrocarbon reserves.
- U.S. Patent No. 5,442,294 describes a method for placing coils in slots at various positions around the periphery of a drill collar at spaced-apart distances along the axis of the collar, to cancel the transmitter primary magnetic field, rather than the more usual induction tool arrangement of mutually-balanced coil arrays. Analysis shows that the Rorden method will suffer from the problem of significant errors due to a high sensitivity to conductive borehole fluids, and a shallow depth of investigation.
- U.S. Patent No. 5,508,616 (Sato, et al.) describes a directional induction tool for wireline logging with inclined coils rotated by a motor that can be used to map conductivity variations around the borehole.
- Many other earlier patents describe similar schemes using stationary orthogonal coil arrays to provide directional information about conductivity anisotropy (for example, see U.S. Patent No. 3,808,520 (Runge), U.S. Patent No. 4,302,723 (Moran), and U.S. Patent No. 4,360,777 (Segesman). In general, these methods are not adaptable to MWD, because they do not solve the drill-collar conductivity problem.
- None of these prior logging tools provide, alone or in combination, an apparatus that is suitable for obtaining directional resistivity information near the bit while a well is being drilled, without being adversely effected by the mass of conductive metal in the drill collars. Such a tool would be desirable to provide real-time directionally focused information regarding nearby geological and fluid boundaries during directional drilling operations.
- the present invention provides a novel logging apparatus by combining coil sensors with a reflector that can be installed in the side of a drill-collar, to make the spatial response of a MWD induction tool directional in an azimuthal sense relative to the borehole axis and to remove the influence of the drill collar material, thus providing real-time directional conductivity data for use during directional drilling operations.
- the present invention provides a method and apparatus for measuring currents induced in a rock medium by a time- varying magnetic field generated by transmitter coils positioned in front of a reflector disposed on a drill collar.
- This arrangement creates and senses a directionally oriented electromagnetic field that is not substantially affected by the body of the conductive drill collar located behind the reflector.
- the invention provides a directional instrument for measuring electrical properties of rock formations near a borehole, comprising a transmitter coil coupled to a signal generator; at least one receiver coil disposed coaxially to the transmitter coil, the axis of the coils defining the axis of the instrument, the at least one receiver coil being coupled to a signal processing circuit; and a conductive reflector spaced from the transmitter coil and the receiver coils, the reflector being generally parallel to the axis of the instrument.
- the reflector may be generally "V shaped in cross-section, with the transmitter coil and the receiver coils arranged within the space defined by the reflector and generally parallel to the reflector.
- this apparatus is positioned in a side pocket formed in a drill collar, so that it can be used near the bit in a drill string.
- a balancing circuit for detecting any imbalance in mutual inductance coupling between the transmitter and receiver coils and for adjusting the magnetic permeability of the core material in at least one of the coils to correct the imbalance.
- This function may be implemented with a direct current generating circuit that is connected to said at least one of the coils so as to pass a selected current therethrough, and wherein the direct current generating circuit is connected to receive a quadrature phase signal from the signal processing circuit.
- the present invention provides a directional resistivity tool for measurement while drilling that is adapted to provide a measurement of formation resistivity on a selected side of a borehole, comprising a drill collar having a side pocket and a flow channel formed therein; an electromagnetic reflector formed in the side pocket; a transmitter coil disposed within the side pocket and operably coupled to a signal generator; and a receiver coil disposed in the side pocket, the receiver coil being coupled to a signal processing circuit.
- the invention provides a method of measuring the apparent conductivity of subsurface formations proximate a borehole in a selected azimuthal direction from the borehole while the borehole is being drilled, comprising providing a directional resistivity measuring tool disposed in a drill collar near the bit, the directional resistivity measuring tool including transmitter and receiver coils and a conductive reflector.
- the method includes energizing the transmitter coil with a selected periodic signal, detecting return signals using the receiver coil, and processing the return signals to obtain the apparent conductivity.
- the directional resistivity measuring tool may comprise in-phase and quadrature phase detectors coupled to the receiver coil, and the processing step may include obtaining an in-phase component of the return signal and a quadrature phase component of the return signal.
- the invention also includes, in some embodiments, techniques for evaluating the conductivity data acquired by the resistivity tool to determine the distance from the tool to a nearby boundary between adjacent beds of rock having different conductivities. These techniques include normalizing the measured apparent conductivity and applying a known relationship between normalized conductivity and distance to a boundary to determine the instantaneous distance between the tool and the boundary during drilling operations. This information can be used to steer the drill bit to maintain a preselected distance between the borehole and the boundary. BRIEF DESCRIPTION OF THE DRAWINGS
- FIG. 1 is a sectional elevation view taken on a plane passing through the long axis of the tool and indicated by the line 1-1 in FIG. 2;
- FIG. 2 is a cross-sectional view through the collar and coils on a plane indicated by the line 2-2 in FIG. 1;
- FIG. 3 is a partial vertical sectional view indicating lines of magnetic field flux;
- FIG. 4 is a horizontal cross-sectional view showing lines of eddy current flow
- FIG. 5 is an illustration of the induction tool operatively placed in a drill-string
- FIG. 6 is a block diagram of electronic circuits that may be used for data acquisition
- FIG. 7 illustrates additional circuits that may be employed to automatically zero mutual errors
- FIG. 8 shows a graph of measured conductivity as a function of distance to a contrasting bed boundary.
- FIG. 9 A and 9B are exemplary graphs of normalized apparent conductivity as a function of distance to an adjacent bed boundary, for low conductivity rock and high conductivity rock, respectively.
- FIG. 10 is an exemplary graph of normalized apparent resistivity as a function of distance to an adjacent bed boundary.
- a solenoidal transmitter coil of wire that is energized with a time- varying (in preferred embodiments, sinusoidal) electric current will generate a proportionate time- varying magnetic field extending in all directions from the axis of the coil, such that in a proximate conductive medium circulating currents will be induced to flow.
- These are commonly known as Foucault or "eddy" currents, and their magnitude is proportional to the conductivity of the medium at distances from the coil much less than the skin-depth in the medium (defined as inversely proportional to the square-root of the product of frequency and conductivity).
- the Foucault currents in turn induce a proportionate voltage in other receiver coils placed in the vicinity, usually coaxially with the transmitter coil.
- the frequency is made low enough to substantially remove skin-effect, so that the maximum depth of investigation may be achieved and the induced voltage may be substantially proportionate to the conductivity of the rock formation at the depth of investigation. If the coils are located in a borehole and the magnetic fields extend equally in all directions, then there is no directional information available in the induced voltage to indicate the presence of a conductivity anomaly on one side of the borehole, and a large mass of conductive metal (such as a steel drill-collar) will introduce a large, uncontrolled receiver voltage that may mask the desired voltage information based on properties of the rock formation.
- this field cancellation extends through the space in front of the plane and focuses the resulting magnetic field in a direction normal to the surface of the plane.
- the reflecting conductive plane simultaneously achieves the objectives of (a) focusing the magnetic fields associated with coils in a preferred azimuthal direction relative to the coil axis, and (b) preventing any interaction of the field with material, such as a drill- collar, placed behind the plane.
- the Law of Reciprocity known to those familiar with this art teaches that the same analysis applies to receiver coils that are sensing magnetic fields as it does to transmitting coils that are generating magnetic fields.
- a conductive medium such as a rock formation placed before an assembly of coils and a reflector will induce a voltage proportionate to the conductivity of the medium in the receiver coils, as with any induction tool. More particularly, a conductivity anomaly, such as a boundary of a rock bed of contrasting conductivity, placed in front of the assembly will be sensed when the instrument is pointed toward the boundary, and a voltage proportionate to the integrated conductivity within the sensitive region may be recorded.
- the precise direction of a bed boundary can be determined by observing "peaks" and "nulls" in the recorded voltage, depending on whether the rock bed being sensed is more or less conductive than the rock immediately surrounding the borehole.
- This method of rotation is quite practical in a normal drilling environment, where the drill-string is continuously turned to drive the drill-bit. More conveniently, when the drill-bit is driven by a down-hole mud motor, the drill-string may be slowly rotated to effect a steering mechanism with a bent-sub, or simply to prevent sticking of the drill-string in the borehole.
- the rotation can be precisely controlled by the rotary table and kelly on the drilling rig, while data from induction and orientation tools near the drill bit may be conveyed to the surface via a mud-pulse telemetry system or other means known in the art.
- FIG. 1 depict two orthogonal sectional views of a preferred embodiment of the instant invention and should be used together to gain a better understanding of the invention.
- an induction tool 10 placed in a side channel of a drill collar 12.
- the tool 10 contains an array of coils, magnetic cores, and a reflector embedded in an insulating material. In the preferred embodiment, these elements are constructed with a particular shape, using specially chosen materials (to be described) to implement an operative sensor package.
- the tool also contains a pressure compensator 14 of conventional design to allow spaces within the sensor package to be filled with insulating oil 16 maintained at a hydrostatic pressure slightly higher than the borehole fluids, thus removing high pressure differentials from the sensor package and preventing ingress of borehole fluids.
- transmitter coil 16 and receiver coils 18, 20 are coaxially positioned within the side channel of drill collar 12.
- the coils are connected to induction tool data acquisition circuits 22 (described below in connection with FIG. 6) by conductive cables 24.
- the apparatus may also include battery and power supply circuitry 26 and memory or telemetry apparatus 28, as are well known in the art and outside of the scope of the present invention.
- Drill collar 12 includes mud channel 30 and threaded couplings 32, 34 for connection of drill collar 12 to adjacent collars or other components of the drill string.
- Magnetic cores 50 are positioned within each coil 16, 18, 20 to allow use of much smaller diameter coils than usual by concentrating the magnetic flux inside the coils. Since induction tools rely on the use of mutual-inductance balance (described in more detail later), it is important to use a low-loss ferromagnetic material for the cores with a permeability that is stable with changes in temperature and pressure.
- suitable cores are type MPP powder-permalloy cores manufactured by Arnold Engineering, Marengo, Illinois, type TH powdered carbonyl iron from TSC Arnold Technologies of Wadsworth, Illinois, and Type 64 Nickel-Zinc Ferrite from Amidon Associates of N. Hollywood, California.
- a plurality of toroid cores may be stacked axially to provide a core length to match the length of the associated coil.
- the length/diameter ratio (£/d) and permeability ( ⁇ ) are of prime importance in determining the gain associated with magnetic flux coupled to the coil and also in reducing the influence of variations of permeability.
- the effective gain, G, of a coil including a core may be calculated as follows:
- G ⁇ / [1 + ⁇ - 1 1.6 + 2.2( / d) 1.5 .
- the transmitter and receiver coils 16, 18, 20 in preferred embodiments of the invention may be wound on a temperature-stable fiberglass/epoxy composite forms using copper Litz wire and connected to electronic circuits by shielded twisted-pair cables 52, 54.
- Suitable Litz wire used in the preferred embodiments is type NELB41/36 for transmitter coils and type NELB16/36 for receiver coils, available from New England Electric Wire Corp., of Lisbon, New Hampshire.
- the coils, cores, and associated cables are installed in a fiberglass/epoxy tube 55 with cylindrical spacers of the same material.
- the magnetic cores 50 may be made by stacking readily available toroid components, leaving a central hole in the cores to pass the cables 52 through in order to make connections to the coils 16, 18, 20. Since nearly all the magnetic flux passes through the cores, very little is intercepted by the cables, which would otherwise be susceptible to induced cross-talk signals.
- the coils may be equipped with electrostatic shields 54, which are well-known in the art, to prevent unwanted capacitive coupling between transmitter coil 16 and receive coils 18, 20.
- the tool also comprises reflector 38, which may consist of a thick sheet of soft- annealed copper or preferably a stacked and laminated assembly of thin soft-copper sheets.
- the total thickness of the reflector is equivalent to at least about six times the skin-depth at the frequency of operation of the tool. At a frequency of 20KHz, this corresponds to a total copper thickness of approximately 0.125 inches.
- the preferred embodiment employs a generally V-shaped reflector 38 as shown in FIG. 2, enclosing the coils 16, 18, 20 on the side nearest the drill-collar axis and opening toward the borehole with an included angle that may be in the range of 60 to 90 degrees in preferred embodiments.
- the drill collar in which the coils are mounted may be made of a conductive material, such as beryllium-copper. In that case, the drill collar itself serves as the reflector, and no additional reflector is required.
- the invention is not limited to such a configuration, but may also incorporate other coil array designs such as the well- known six-coil array, or multiple coil arrays to provide multiple spatial responses. Also, the roles of the transmitter and receiver coils can be reversed in any tool design, as is well known in the art. These alternative embodiments would be obvious extensions of the present invention.
- Insulating material 36 is employed to encase the coils and other components and to fill the side pocket formed in the drill collar, as shown in FIG. 1 and 2.
- This material is a structural element that retains the tool components in the collar, as well as a shock-isolation medium protecting the sensor components from stresses caused by impact between the collar 12 and the borehole wall.
- the material preferably has a mechanical modulus of elasticity close to that of the collar material, while being a low-loss electrical insulator to allow magnetic flux to pass freely therethrough.
- An example of a suitable material for use in preferred embodiments of the invention is a composite of a high-temperature rated epoxy such as Duralco 4460 manufactured by Cotronics Corp.
- the insulator assembly may be made in layers with glass fiber reinforcement and cast in a mold to final dimensions, using well-known techniques.
- the portion of the insulator in contact with the borehole may be further strengthened and made more abrasion-resistant by the incorporation of up to, for example, 20% Silicon Carbide powder, also made by Norton Industries, in a layer having a depth of, for example, at least 0.25 inches. Silicon Carbide is a semiconducting material, so will introduce error signals if its concentration is too high.
- FIG. 3 illustrates how, in a preferred embodiment, the upper transmitter coil 16 will generate a time-harmonic primary magnetic field extending out into adjoining rock formations 58.
- Imaginary solid lines of magnetic flux 60 are intended to convey qualitatively the intensity and direction of the flux.
- This primary flux will generate Foucault currents in any proximate conductive rock medium 58 which, in turn, generate a secondary flux 62 (shown by dashed lines) that couples to and induces a voltage in the receiver coils 18, 20.
- the secondary flux 62 opposes the primary flux 60 as indicated by noting the direction of the arrow heads on the flux lines.
- This diagram also shows how reflector 38, even though it is not a perfect conductor, will direct and focus the magnetic flux in the desired direction of investigation.
- the distance between transmitter coil 16 and the main receiver coil 20 may be, for example, about 40 inches, with the bucking receiver coil 18 placed, for example, about 34 inches from the transmitter.
- the number of turns of wire on each coil may be chosen to achieve zero mutual coupling between transmitter coil 16 and the series-opposition connected receiver coils 18, 20.
- FIG. 4 illustrates the lines of Foucault currents 64 flowing in a conductive medium 58 proximate the tool 10 in plane 4-4 passing through the main receiver coil, as indicated by section line 4-4 in FIG. 3.
- the current flow is confined primarily to a region generally in the direction faced by the coil array and substantially bounded by the angle subtended by the reflector.
- the theoretical spatial response of such a system may be calculated using finite element modeling computer software, which is available from several software companies, using techniques that are well known in the art.
- FIG. 5 is a general view of induction logging tool 10 placed in drill-collar 12 during a directional-drilling operation using a preferred embodiment of the present invention.
- Induction tool 10 may be combined with orientation sensors and a mud-pulse telemetry system, which may be located in instrument package 70, disposed within collar 12.
- the mud pulse system which is well known in the art, provides for direct transmission of data to the surface during drilling operations where it can be used to facilitate geosteering techniques.
- the data may be detected at the surface by mud-pulse receiver 78 for decoding, storage and display on operator panel 80.
- Induction tool 10 may alternatively be placed below a mud- motor very close to the drill-bit 76.
- a short-range telemetry system may be employed in such a system to communicate resistivity data past the motor to a mud-pulse telemetry system, so that resistivity data may be acquired as close as possible to the bit.
- placing the induction tool 10 in a side-pocket of collar 12 leaves the bore 30 of collar 12 open for a drive-shaft between the mud motor and the bit.
- FIG. 6 is a block-diagram of a preferred embodiment showing exemplary electronic circuits that may be used to acquire data using the sensor coil arrangement described above. It is desirable, in view of the error-signal contributions expected because magnetic cores 50 and reflector 38 are not perfect materials, to measure the in-phase and quadrature components (shown here as the "I” or in-phase and "Q” or quadrature phase components) of the received signal voltages, where phase is measured relative to the phase of the transmitter energizing current.
- I in-phase and quadrature components
- digital synthesizer circuit 86 generates a spectrally pure sine-wave output 88 at a frequency preferably in the range of 20KHz to 80KHz and supplies it to power amplifier (PA) 90, which drives a high oscillating current through transmitter coil 16.
- PA power amplifier
- the receiver coils, main receiver 18 and bucking receiver 20, which are connected in phase opposition to cancel direct mutual coupling to the transmitter primary flux, are connected through multiplexing switch 92 to a low-noise amplifier (LNA) 94.
- Switch 92 can alternately connect a calibration signal derived from PA 90 output current flowing through transformer 96 and resistor 98 to LNA 94.
- Amplified signals output from the LNA are supplied to "I" phase-sensitive detector (IPSD) 100 and “Q” phase-sensitive detector (QPSD) 102, which have outputs that are connected to filters 104,106 selected to remove undesired harmonic components.
- the outputs of filters 104 and 106 are connected to switch 108, which alternately connects the in-phase and quadrature signals to A/D converter 110.
- Digital data output from A/D converter 110 are supplied to telemetry and/or storage circuitry 112 for storage or for transmission to the drilling rig by mud-pulse telemetry or other techniques known in the art.
- Digital control circuits 114 control the operation of switches 92, 108 and A/D converter 110 to acquire a desired sequence of "I” and "Q” samples of the received voltage from receiver coils 18, 20 and calibration signals from transformer 96.
- All induction tools in use today comprise coil arrays with zero mutual inductance coupling between transmitter coils and receiver coils. There are two important reasons for this; first, the primary magnetic flux is usually several orders of magnitude larger than the secondary flux, and if not balanced out it would induce a voltage in the receiver coils that would overload sensitive electronic amplifiers and mask formation returns. Second, the mutual balance condition is required to minimize sensitivity of the tool to conductive drilling mud in the borehole 75. Specifically, the first derivative of the integrated radial geometrical factor ts zero at the axis of the coils when mutual balance is achieved. Any perturbation of the mutual balance has a significant effect on tool performance and accuracy. Normally, great effort is made to design coil arrays with high mechanical stability, and potentially unstable magnetic cores are avoided. Various schemes to cancel error signals due to unbalanced coils are known in the art, including injection of compensating signals into the input of the LNA circuits, but these methods do not correct for variations in the borehole mud conductivity, thereby introducing other unpredictable error signals.
- FIG. 7 which is to be considered in combination with FIG. 6 to illustrate an extension of that basic block diagram
- the filtered output 120 of "Q" PSD 102 is passed to the input of integrator operational amplifier 122 via switch 124 that is closed only during the time when input of the LNA 94 is connected to the receiver coils 18, 20 by switch 92.
- a voltage at output 126 of integrator 122 is supplied to a resistor/capacitor network 128 configured to force a D.C. bias current through receiver coils 18, 20 (proportional to the integrator output) while passing the A.C. signals through capacitors 130, 132 to switch 92 and LNA 94 as before.
- This apparatus makes use of the phenomenon that the initial permeability of a ferromagnetic material, such as core 50 placed inside coil 20, is sensitive to the intensity of the steady magnetic flux passing through it.
- a D.C. bias current passed through a receiver coil will create a biassing magnetic flux that modulates the permeability of the magnetic core therein and changes the mutual balance of the coil sensor array.
- any voltage appearing at the output of "Q" PSD 102 is amplified and applied as a bias current 134 to receiver coils 18, 20 in a negative feedback method to immediately suppress "Q" PSD output, which is the component of the received voltage that is primarily responsive to unbalanced mutual coupling.
- coils 18, 20 are preferably mechanically positioned very close to the nominal mutual balance locations within the sensor package, but intentionally slightly offset therefrom to allow the bias current circuit to act to maintain the balance with an adequate dynamic range available to correct for temperature drift. By extension, if the coil array becomes out of mutual balance for any reason, this circuit will automatically correct it.
- Integrator amplifier 122 is used because variations in mutual balance are expected to be quite slow in time, while it is important that the bias circuit should not inject any noise signals into the sensitive LNA input.
- the bias current may be passed through only one of the receiver coils to provide a stronger modulation of mutual balance, but it is preferable to connect the circuit to both coils as shown because individual coil connections are not ordinarily readily accessible within the electronic circuit pressure housing 22.
- an increase of bias current 22 causes a decrease in permeability, but in no case should the bias be more than a small fraction of the saturation flux density of the cores. The method therefore does not modify the inherent gain factor of the tool to any significant degree, which is controlled primarily by the length/diameter ratio of the cores, as previously described.
- the bias current may be selected by periodically transmitting a signal having a different frequency than that used for conductivity measurements and measuring the "I" and "Q" return signals at that different frequency.
- One skilled in the art could design circuitry to implement such an embodiment.
- a piston pressure compensator 14 transmits borehole pressure to internal insulating oil 16 in fiberglass tube 55 with slight excess pressure of 20 to 50 psi to prevent contamination of the sensor package by borehole fluids.
- the insulating oil fills any gaps between instrument components and serves to equalize the pressure throughout the instrument.
- the coil/core assemblies may be exposed to hydrostatic pressures of as high as 20,000 psi.
- the modification comprises selecting the gain of integrator amplifier 122 so that large "Q” signals drive the bias current circuit to limit at a known value, at which time the bias current remains fixed.
- the varying digitized "Q" signal may then be employed (with a suitable offset correction) in known skin-effect correction algorithms for interpreting rock conductivity.
- Another source of "Q" signal occurs when the tool is placed near any ferromagnetic material with a permeability even fractionally higher than free space. Examples include steel particles shed into the drilling mud by abrasion of the drill-string against the borehole wall, and naturally occurring minerals such as pyrite and siderite. These events are generally of little interest to the log analyst, and they typically produce only a small "Q" signal, so they are effectively suppressed by the method of the present invention. Shock-mounting materials such as rubber sleeves may be placed around the coils and cores to dampen microphonic noise signals that might be induced in the coils by vibrations in the kilohertz frequency range.
- PSD circuits 100, 102 which may be synchronous detectors with very narrow bandwidth.
- the effective noise bandwidth may be further reduced by data processing techniques on the digitized samples of the "I" and "Q" signals, such as averaging or filtering as is known in the art.
- preferred embodiments include circuits for acquiring digitized samples of receiver coil voltages representing formation conductivity and samples of calibration voltages. These samples may be further processed to extract corrected values of apparent formation conductivity without errors due to temperature drift of amplifier gain or phase-shift, or A/D gain.
- Cai and Caq may be used in various algorithms to interpret true formation conductivity Ct, which are well known in the art and beyond the scope of this disclosure.
- the Caq component may often be discarded since it is most corrupted by residual effects of changes in mutual balance of the coil array. A most important benefit of this ratiometric method is to greatly increase the accuracy and stability of the tool.
- the tool 10 may be rotated in the borehole by rotating the drill string. Any nearby rock bed that is more conductive than the rock immediately surrounding the borehole will be sensed as an increase in apparent conductivity Cai when the tool is angularly oriented facing toward the more conductive bed.
- the direction of the bed boundary relative to the tool may be determined by correlation of the measured conductivity output with orientation sensors included in a drill collar (which are well known in the art) and mechanically aligned with the induction sensor package.
- orientation sensors included in a drill collar which are well known in the art
- a less conductive bed near the borehole appears as a decrease in Cai and in Ct when the tool is facing that bed.
- FIG. 8 shows an example of the integrated radial component of the geometrical factor in the most sensitive azimuthal direction.
- This graph shows normalized apparent conductivity plotted as a function of distance to the boundary between the bed adjacent the borehole and another bed having contrasting conductivity, for a given formation geometry and conductivities.
- the apparent conductivity Cai and the adjacent bed conductivity Cr are normalized by dividing by the local rock conductivity C £ around the borehole.
- the distance to the adjacent bed may be solved by plotting Cai/ C £ across to the curve and finding the intercept at distance D.
- This method requires knowledge of Cr and C £ , which may be obtained from offset well logs, or preferably from measurements in the same rock beds at other points or in other directions while drilling through them.
- FIG. 9 A shows an example of how the radial component of the geometrical factor in the most sensitive azimuthal direction may be plotted as a useful measure of the influence of an adjacent rock bed having a contrasting conductivity. It is computed by calculating or otherwise determining the expected apparent conductivity for different distances to the bed when the rock conductivities are relatively low and the local conductivity is higher than that of the contrasting rock bed.
- the exemplary graphs presented as Figures 9 A, 9B and 10 were generated using a mathematical model for a tool with a spacing of 40 inches between the main transmitter and receiver coils.
- Cna varies from a value of 0 to a value of 1 as the tool approaches the adjacent bed. Also illustrated by dashed lines is an example computation of the distance from the tool to an adjacent bed.
- This graphic technique may, of course, be implemented numerically by a computer.
- This normalization method requires knowledge of conductivity values Cs and Cr, which may be found from offset well logs. These values may also be obtained from measurements in the rock beds of interest at other points in the borehole and by measurements made by facing the tool in other rotational directions (e.g., not facing the boundary). For example, the conductivity of an adjacent bed (Cr), such as a capping shale bed, may be determined using this tool while drilling through that bed to reach the reservoir bed. The conductivity of the reservoir bed (Cs) may then be determined using this tool by pointing the tool into the reservoir bed, away from the bed boundary. Then, the tool may be pointed toward the bed boundary to obtain the apparent conductivity (Ct), so that the distance to the boundary may be determined as described above.
- Cr adjacent bed
- Cs reservoir bed
- the process of directional drilling may be conducted by continually gathering conductivity data in various parts of the formations penetrated by the borehole, which can than be used in the interpretation of additional data from the same borehole.
- the distance to the adjacent bed boundary may be automatically measured and computed by the tool and the associated processing equipment and displayed to the driller for use in controlling the progress of the borehole as it is drilled.
- this reduction in depth of investigation is due primarily to the phenomenon of skin-effect.
- a tool employing this invention can, however, still usefully sense the distance to rock beds at distances up to about 6 feet in this higher conductivity environment.
- this method can provide a suitable apparent depth of investigation.
- This resistivity algorithm is potentially more sensitive to inaccuracy in the measurement of Ct or in the assumed values of Cs and Cr, but improvement in accuracy of these values may be improved by additional measurements made while drilling, using additional information obtained from the tool.
- the present invention thus provides an improved directional induction logging tool suitable for installation in a drill collar for measurement- while-drilling.
- This tool provides real-time formation data with a relatively deep depth of investigation, which will be particularly useful for locating formation boundaries during geosteering operations.
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Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA002318390A CA2318390C (en) | 1998-01-09 | 1999-01-08 | Electromagnetic logging tool with reflector for directional sensing |
AU23145/99A AU2314599A (en) | 1998-01-09 | 1999-01-08 | Electromagnetic logging tool with reflector for directional sensing |
EP99903027A EP1046065B1 (en) | 1998-01-09 | 1999-01-08 | Electromagnetic logging tool with reflector for directional sensing |
DE69939154T DE69939154D1 (en) | 1998-01-09 | 1999-01-08 | ELECTROMAGNETIC BOLL MEASURING DEVICE WITH REFLECTOR FOR DIRECT SENSITIVITY |
NO20003518A NO329771B1 (en) | 1998-01-09 | 2000-07-07 | Electromagnetic logging tool with reflector for directional folding |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US09/005,068 | 1998-01-09 | ||
US09/005,068 US6100696A (en) | 1998-01-09 | 1998-01-09 | Method and apparatus for directional measurement of subsurface electrical properties |
Publications (1)
Publication Number | Publication Date |
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WO1999035515A1 true WO1999035515A1 (en) | 1999-07-15 |
Family
ID=21714007
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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PCT/US1999/000502 WO1999035515A1 (en) | 1998-01-09 | 1999-01-08 | Electromagnetic logging tool with reflector for directional sensing |
Country Status (7)
Country | Link |
---|---|
US (1) | US6100696A (en) |
EP (1) | EP1046065B1 (en) |
AU (1) | AU2314599A (en) |
CA (1) | CA2318390C (en) |
DE (1) | DE69939154D1 (en) |
NO (1) | NO329771B1 (en) |
WO (1) | WO1999035515A1 (en) |
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EP1163539A1 (en) * | 1999-02-22 | 2001-12-19 | Halliburton Energy Services, Inc. | Directional resistivity measurements for azimuthal proximity detection of bed boundaries |
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CN114856550A (en) * | 2022-05-11 | 2022-08-05 | 西南石油大学 | Device and method for accurately positioning petroleum casing pipe based on geomagnetic anomaly marker |
CN114856550B (en) * | 2022-05-11 | 2023-04-04 | 西南石油大学 | Device and method for accurately positioning petroleum casing pipe based on geomagnetic anomaly marker |
Also Published As
Publication number | Publication date |
---|---|
DE69939154D1 (en) | 2008-09-04 |
NO329771B1 (en) | 2010-12-13 |
EP1046065A1 (en) | 2000-10-25 |
US6100696A (en) | 2000-08-08 |
NO20003518D0 (en) | 2000-07-07 |
CA2318390A1 (en) | 1999-07-15 |
AU2314599A (en) | 1999-07-26 |
NO20003518L (en) | 2000-09-07 |
CA2318390C (en) | 2007-05-08 |
EP1046065B1 (en) | 2008-07-23 |
EP1046065A4 (en) | 2001-01-24 |
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