AN APPARATUS ACCURATELY MEASURING PROPERTIES OF A FORMATION

Abstract: A transverse induction logging tool (9) having a transmitter (18) and receiver (19) for downhole sampling of formation properties, the tool having a symmetrical shielded split-coil transmitter coil (30, 32) and a bucking coil (33) interposed between the split transmitter coils (30, 32) to reduce coupling of the transmitter time varying magnetic field into the receiver (19). The tool provides symmetrical shielding of the coils and grounding at either the transmitter or receiver end only to reduce coupling of induced currents into the received signal. The tool provides an insulator between receiver electronics and the conductive receiver housing having contact with conductive wellbore fluid, to reduce parasitic current flowing in a loop formed by the upper housing, feed through pipe, lower housing and wellbore fluid adjacent the probe housing or mandrel. An internal verification loop is provided to track changes in transmitter current in the real and quadrature component of the received data signal. A galvanic electrode (120) is housed in the same mandrel with the induction logging receiver (19) and transmitter (18).

Description: BACKGROUND OF THE INVENTION AN APPARATUS ACCURATELY MEASURING PROPERTIES OF A FORMATION Field of the Invention The invention is related generally to the field of electromagnetic induction resistivity well logging instruments wherein the induction antennas are oπented transverselv with respect to the longitudinal axis of the instrument More specifically, the invention is related to an apparatus for transverse electromagnetic induction resistivity well logging operating m the frequency and or time domain with reduced errors introduced into the acquired logging data Description of the Related Art Electromagnetic induction resistivity well logging instruments are well known in the art Electromagnetic induction resistivity well logging instruments are used to determine the electπcal conductivity, and its converse, resistivity, of earth formations penetrated by a borehole Formation conductivity has been determined based on results of measunng the magnetic field of eddy currents that the instrument induces m the formation adjoining the borehole The electπcal conductivity is used for, among other reasons, mferπng the fluid content of the earth formations Typically, lower conductivity (higher resistivity) is associated with hydrocarbon-beaπng earth formations The physical pπnciples of electromagnetic induction well logging are well descπbed, for example, in, J H Moran and K S Kunz, Basic Theory of Induction Logging and Application to Study of Two-Coil Sondes, Geophysics, vol 27, No 6, part 1, pp 829-858, Society of Exploration Geophysicists, December 1962 Many improvements and modifications to electromagnetic induction resistivity instruments descπbed m the Moran and Kunz reference, supra, have been devised, some of which are descπbed, for example. m U S patent no 4.837.51 " issued to Barber, in U S patent no 5,157,605 issued to Chandler et al and in U S patent no 5,600.246 issued to Fanmi et al The conventional geophysical induction resistivity well logging tool is a probe suitable for loweπng into the borehole and it compπses a sensor section containing a transmitter and receiver and other, pπmaπly electπcal, equipment for measunng data to infer the physical parameters that characteπze the formation The sensor section, or mandrel, with the borehole axis The electπcal equipment generates an electπcal voltage to be further applied to a transmitter induction coil, conditions signals coming from receiver induction compnses induction transmitters and receivers positioned along the instrument axis, arranged m the order according to particular instrument or tool specifications and oπented parallel coils, processes the acquired information, stores or by means of telemetry sending the data to the earth surface through a wire line cable used to lower the tool into the borehole In general, when using a conventional induction logging tool with transmitters and receivers (induction coils) oπented only along the borehole axis, the hydrocarbon-beanng zones are difficult to detect when they occur m multi-layered or laminated reservoirs These reservoirs usually consist of thin alternating layers of shale and sand and, oitentimes. the lavers are so thin that due to the insufficient resolution of the conventional logging tool the\ cannot be detected individually In this case the average conductivity of the formation is evaluated Conventional induction well logging techniques employ coils wound on an insulating mandrel One or more transmitter coils are energized by an alternating current The oscillating magnetic field produced by this arrangement results m the induction of currents in the formations which are nearly proportional to the conductivity of the formations These currents, in turn, contπbute to the voltage induced m one or more receiver coils By selecting only the voltage component which is in phase with the transmitter current, a signal is obtained that is approximately proportional to the formation conductivity In conventional induction logging apparatus, the basic transmitter coil and receiver coil has axes which are aligned with the longitudinal axis of the well logging device (For simplicity of explanation, it will be assumed that the bore hole axis is aligned with the axis of the logging device, and that these are both m the vertical direction Also single coils will subsequently be referred to without regard for focusing coils or the like ) This arrangement tends to induce secondary current loops m the formations that are concentnc with the vertically oπented transmitting and receiving coils The resultant conductivity measurements are indicative of the hoπzontal conductivity (or resistivity) of the surrounding formations There are, however, vaπous formations encountered m \\ ell logging which have a conductiv lty that is amsotropic Anisotropy results from the manner m which formation beds were deposited by nature For example, "umaxial anisotropy" is charactenzed by a difference between the hoπzontal conductivity, in a plane parallel to the bedding plane, and the vertical conductivity, in a direction perpendicular to the bedding plane When there is no bedding dip, hoπzontal resistivity can be considered to be in the plane perpendicular to the bore hole, and the vertical resistivity in the direction parallel to the bore hole Conventional induction logging devices, which tend to be sensitive only to the hoπzontal conductivity of the formations, do not provide a measure of vertical conductivity or of anisotropy Techniques have been developed to determine formation anisotropy See, e g U S Patent No 4,302,722 Transverse anisotrophy often occurs such that vaπations m resistivity occur in the azimuthal direction Techniques for addressing such full anisotropy are discussed in WO 98/00733 Thus, in a vertical borehole, a conventional induction logging tool with transmitters and receivers (induction coils) onented only along the borehole axis responds to the average hoπzontal conductivity that combines the conductivity of both sand and shale These average readings are usually dominated by the relatively higher conductivity of the shale layers and exhibit reduced sensitivity to the lower conductivity sand layers where hydrocarbon reserves are produced. To address this problem, loggers have turned to using transverse induction logging tools having magnetic transmitters and receivers (induction coils) onented transversely with respect to the tool longitudinal axis Such instruments for transverse induction well logging has been descπbed m PCT Patent publication WO 98/00733 by Bear et al. and U.S. Patent Nos 5,452,761 by Beard et al., U S Patent No. 5.999.883 by Gupta et al , and 5,781,436 by Forgang et al In the transverse induction logging tools the response of transversal coil arrays is also determined by an average conductivity, however, the relatively lower conductivity of hydrocarbon-beaπng sand layers dominates m this estimation In general, the volume of shale/sand in the formation can be determined from gamma-rav or nuclear well logging measurements Then a combination of the conventional induction logging tool with transmitters and receivers oπented along the well axis and the transversal induction logging tool can be used for determining the conductivity of individual shale and sand layers One, if not the mam. difficulties in interpreting the data acquired by a transversal induction logging tool is associated with vulnerability of its response to borehole conditions Among these conditions is the presence of a conductive well fluid as well as wellbore fluid invasion effects A known method for reducing these unwanted impacts on the transversal induction logging tool response was disclosed in L. A. Tabarovsky and M. I. Epov, Geometric and Frequency Focusing in Exploration of Anisotropic Seams. Nauka, USSR Academy of Science, Siberian Division, Novosibirsk, pp. 67-129 (1972) and L. A. Tabarovsky and M. I. Epov, Radial Characteristics Of Induction Focusing Probes With Transverse Detectors In An Anisotropic Medium. Soviet Geology And Geophysics, 20 (1979), pp. 81-90. The known method has used a transversal induction logging tool comprising a magnetic transmitter and receiver (induction coils). By madiating a magnetic field the induction transmitter induces currents in the formation adjoining the borehole; in turn, the receivers measure a responding magnetic field due to these currents. To enable a wide range of vertical resolution and effective suppression of the unwanted borehole effects, measurements of magnetic field from the formation can be obtained with different transmitter and receiver spacings that facititate geometric focusing and different frequencies to facilitate frequency focusing. See, for example U.S. Patent No. 5,703,772 by Beard. However, even with these modifications, the data logs obtained with a conventional transversal induction logging instrument can be difficult to interpret, that has been exacerbated while logging through a sequence of layers. In the induction logging instruments the acquired data quality depends on the formation electromagnetic parameter distribution (conductivity) in which the tool induction receivers operate. Thus, in the ideal case, the logging tool measures magnetic signals induced by eddy cunents flowing in the formation. Variations in the magnitude and phase of the eddy cunents occurring in response to variations in the formation conductivity are reflected as respective variations in the output voltage of receivers. In the conventional induction instruments these receiver induction coil voltages are conditioned and then processed using analog phase sensitive detectors or digitized by digital to analog converters and then processed with signal processing algorithms. The processing allows for determining both receiver voltage amplitude and phase with respect to the induction transmitter current or magnetic field waveform. It has been found convenient for further uphole geophysical interpretation to deliver the processed receiver signal as a vector combination of two voltage components: one being in-phase with transmitter waveform and another out-of-phase, quadrature component. Theoretically, the in-phase coil voltage component amplitude is the more sensitiv e and noise-free indicatoi of the formation conductivity There are a few hardware margins and software limitations that impact a conventional transversal induction logging tool performance and result m eπors appeaπng m the acquired data The general hardware problem is typically associated with an unavoidable electrical field that is irradiated by the tool induction transmitter simultaneously with the desirable magnetic field, and it happens in agreement with Maxwell's equations for the time arying field The transmitter electπcal field interacts with remaining modules of the induction logging tool and with the formation, however, this interaction does not produce any useful information Indeed, due to the always-existing possibility for this field to be coupled directly into the receiver part of the sensor section through parasitic displacement currents. it mtroduces the noise When this coupling occurs, the electncal field develops undesirable electπcal potentials at the input of the receiver signal conditioning, pπmaπly across the induction coil receiver, and this voltage becomes an additive noise component to the signal of interest introducing a systematic error to the measurements The problem could become even more severe if the induction logging tool operates m wells containing water-based fluids The water-based mud has a significantly higher electπcal permittivity compared to the air or to the oil-based fluid In the same time, the electπcal impedance to the above mentioned displacement currents can be always considered as capacitive coupling between the source - the induction transmitter and the point of coupling This circumstance apparently would result in a fact that capacitive coupling and associated systematic errors are environment dependant because capacitive impedance will be converse to the well mud permittivity The conventional method in reducing this capacitive coupling m the induction logging instrument lays in using special electπcal (Faraday) shields wrapped around both transmitter and receiver induction coils These shields are electπcally attached to the transmitter analog ground common point to fix their own electπcal potential and to provide returns of the displacement currents back to their source - transmitter instead of coupling to any other place in the tool However, geometry and layout effectiveness of Faraday shields becomes marginal and contradictory m the high frequency applications where conventional transverse induction tools can operate These limitations occur due to the attenuation these shields introduce to the magnetic field known m the an as a shield "skm effect" The shield design limitations are unavoidable and, therefore, the possibility for the coupling through displacement currents remains Another source of hardware errors introduced mto the acquired log data is associated electπcal potential difference between different tool conductiv e parts and. m particular, between transmitter and receiver pressure housings if these modules are spaced apart or galvamcally separated These housings cover respective electronic modules and protect them from exposure to the harsh well environment including high pressure and dπllmg fluids Typically, the pressure housing has a solid electπcal connection to the common point of the electronic module it covers, however, design options with "galvamcally" floating housings also exist If for some reasons, mamly - imperfections m conventional induction tools - the common points of different electronic modules have an electπcal potential difference between them, this difference will appear on the pressure housings It may occur even in a design with "galvamcally" floating housings if the instrument operates at the high frequencies and, in particular, through the capacitive coupling that these metal parts might have to the electronic modules encapsulated m a conductive metallic package Having different electπcal potentials on separate pressure housings will force the electncal current to flow between them This current would have a conductive nature and high magmtude if the induction tool is immersed in a conductive well fluid and it will be a displacement current of typically much less magnitude for tool operations m a less conductive or oil-based mud In both cases this current is time varying, therefore, it produces an associated time varying magnetic field that is environmentally dependent and measured by the induction receiver For those who are skilled in the art it should be understood that the undesirable influence of those currents on the log data would be significantly higher m the conventional transverse induction tool compared to the instruments having induction coils coaxial with the tool longitudinal axis onlv In particular, this is due to the commonly accepted overall design geometry of induction logging tools where transmitter and receiver sections are axially separated bv the mandrel It can be noticed that employing the induction tool in the logging stnng where it has mechamcal and electπcal connections (including telemetry) with instruments positioned both above and below could also result m the appearance of the above-mentioned currents Another source of the housings' potential offsets is the induction tool transmitter itself The remaining electπcal field that this transmitter irradiates simultaneously with a magnetic field could be different on the surface of separate pressure housings Seventy of this error also depends on Faraday shields ' imperfections as descπbed earlier There is an additional problem that the potential difference creates in conventional tool layouts having transmitter and receiver electronic modules spaced apart and using interconnection wires running throughout the sensor (mandrel) section These wires should be electrically and magnetically shielded from induction receivei coils in the sensor section The entire bundle of wires is placed inside of a highly conductive metal shield that is electncallv connected to the common points of separated transmitter and receiver electronic modules This shield's thickness is selected to enable sufficient suppression of mutual crosstalk between wires and sensor section coils withm the entire operational frequency bandwidth and, pnmanly, at its lower end. In some cases, this shield is a hollow copper pipe with a relatively thick wall However, besides protecting the sensor section transmitter and receiver coils and interconnecting wires from mutual crosstalk, this shield simultaneously creates a galvamc path for the currents that could be dπven by pressure housings and/or electromc potential difference. This path apparently exists along the shield's external surface. The time varymg currents also generate a respective magnetic field that crosses induction receiver coils and induces error voltages Unfortunately, these enor voltages are also environmentally dependent and their changes cannot be sufficiently calibrated out duπng tool manufactuπng The overall analysis of the potential difference influence demonstrates that in the conductive well fluid, galvamc currents flowmg through the fluid along external surface of the induction tool would dommate and, decreasmg fluid conductivity redirects these currents to flow along the internal connection between housings The superposition and magnitude of these galvanic currents strongly depend up on the ambient temperature that pushes the conventional induction tool performance to further detenoration Another source of systematic errors introduced in the log data is directly determined by uncertainties in mechamcal dimensions of multi-component transmitter and receiver coils in the sensor section related both to their overall dimensions and positions with respect to each other Thus, to keep required signal phase relationships, conventional tool designs have relied on the mechanical stability and electncal properties of advanced ceramics and plastic mateπals to build the mandrel However, even slight physical assembly deviations in the coil wires position and non-uniform coil form mateπal temperature dependencies might destroy a factory pre-set bucking (compensation of the transmitter pπmary magnetic field coupled in the receiver coil) duπng well logging, and create non-recoverable errors due to mechanical displacement or imperfections Another limitation found m certain induction instrumentation systems is that an insufficient number of signal samples that are gathered for appropπate data stacking Such data insufficiency occurs due to the necessary measurement "idle time 1 ' required for sequentially changing the operational transmitter frequency in a switched frequency tool It can be demonstrated that by simply switching the transmitter frequency from one frequency to another requires a finite amount of decay time for spuπous transient transmitter electronic signals to decay to a sufficiently low level to obtain accurate data measurements If during this "idle tune" the tool continues to take samples or measurements, these measurements will be inaccurate and essentially useless Therefore, pπor receiver designs have provided for "idle time" windows in the measurements during transient decay time, thereby potentially stacking a relatively small and possibly insufficient number of data samples. A better instrumentation design would drastically reduce required idle time Each of the above- mentioned problems, by itself or a combination with another problem adds to the data error, thereby decreasing the accuracy of the induction downhole tool samples and measurements Finally, as discussed m the U S Patent No 3,124,742 by Schneider, galvamc electrodes used in conjunction with induction coils are useful, however, subject to the above mentioned problems SUMMARY OF THE INVENTION It is an object of the present invention to advance the performance of wellbore induction logging tools operating in the frequency and/or time domain The present invention improves measurement of the formation induction response m the presence of the pπmary magnetic field generated by a logging tool's transmitter In a preferred embodiment of the present invention, a structure is provided having a new combination of electncal and mechamcal design features which provide structure for high thermal stability coil forms for the tool's mduction transmitter and receiver magnetic antenna coils, thereby improving the temperature stability of the antenna coil The present invention also provides a single coil venfication transmitter for in situ veπfication of the real and phase-shifted quadrature components of data collected by the tool dunng operation It is another object of the present mv ention to provide the tool sensor assembly structure that exhibits improved symmetry m the transmitter and receiver wiπng, shielding and input circuitry to minimize systematic errors due to capacitive coupling of electncal field induced by the logging tool's transmitter signal into the tool's receiver circuitry It is another object of the present invention to provide electπcal grounding and isolation to the receiver and electπcally isolate the receiver electronics from the mandrel or housing, or alternatively, provide electπcal grounding to the transmitter and let the receiver electronics electncally float to reduce errors caused by potential differences between galvamcally separated receiver and transmitter housings m a logging tool The present invention decreases the influence of electπcal field errors by providmg floating electronics dπvmg transmitter coils and high-speed differential amplifiers in the receiver signal conditioning circuitry Employing this combination enables a high rejection of the parasitic signal introduced as the common mode voltage at the receiver input. It is another object of the present invention to provide a sweep oscillator to obtam the pπmary transmitter magnetic field waveforms for continuous formation response sampling necessary rate sufficient for appropπate data stacking In one aspect of the invention, a logging tool is provided for measunng the properties of a geological formation adjacent to a borehole compnsmg a transmitter compπsmg at least one coil for inducing eddy currents in the formation, a receiver compnsmg at least one coil, and an analog ground connection to at least one of the transmitter, and, the receiver for reducing a galvamc current flow between the transmitter and the receiver In another aspect of the invention a logging tool is provided further compnsmg an insulator for insulating the receiver from electncal contact with the housing and thus the bore hole In another aspect of the invention a logging tool is provided further compnsmg insulating mateπal adjoining the receiver In another aspect of the invention a loggmg tool is provided further compnsmg a feed through pipe having an insulator between the feed through pipe and the receiver. In another aspect of the invention a logging tool is provided further comprising an analog ground connection isolated from a housing for at least one of the transmitter, and, the receiver. In another aspect of the invention a logging tool is provided further comprising an oscillator having a transmitted signal frequency swept over a frequency range. In another aspect of the invention a logging tool is provided further compnsing a split-coil transmitter having bucking coil interposed between the split transmitter coils. In another aspect of the invention a logging tool is provided further comprising a split-coil transmitter comprising symmetrical coils. In another aspect of the invention a logging tool is provided further comprising a spiit-coil transmitter symmetrical shield. In another aspect of the invention a logging tool is provided further comprising a bucking coil shield. In another aspect of the invention a logging tool is provided further comprising a verification winding for coupling a verification signal into the receiver coil. In another aspect of the invention a logging tool is provided further comprising a controllable phase shifting element in the verification check winding to couple a controllable phase shifted and or quadrature verification signal into the receiver coil. In another aspect of the present invention a galvanic electrode and current source are housed in the same mandrel with the induction receiver and transmitter for complementary formation resistivity measurement and interpretation. BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 shows schematically a wellbore extending into a laminated earth formation, into which wellbore an induction logging tool as used according to the invention has been lowered. Figure 2 A illustrates a conventional resistivity measurement in the vertical direction. Figure 2B illustrates a preferred resistivity measurement in the horizontal direction. Figure 3 is a schematic diagram illustrating a preferred embodiment of the split coil transmitter and bucking coil provided by the present invention. Figure 4 is a schematic diagram illustrating a prefened embodiment of the shielding and electrical grounding provided by the present invention. Figure 5 is a schematic diagram illustrating a preferred embodiment of the cunent summation and cancellation provided by the present invention. Figure 6A is a schematic diagram illustrating a preferred embodiment of the shielding and grounding structure provided by the present invention Figure 6B is a schematic diagram illustrating an alternative embodiment of the shielding and grounding structure provided by the present invention Figure 6C is a schematic diagram illustrating an alternative embodiment of the shielding and grounding structure provided by the present invention Figure 7 is a schematic diagram illustrating a waveform response of a conventional oscillator provided by the present invention Figure 8 is a schematic diagram illustrating a waveform response of the sweep oscillator provided by the present invention Figure 9 is schematic representation of a preferred sensor stability v eπfication loop is illustrated Figure 10 illustrates an alternative embodiment of the invention compnsmg the induction tool along with a galvanic electrode pair on the same mandrel Figure 11, illustrates an alternative embodiment of the invention compnsmg the induction tool along with a single galvamc electrode on the same mandrel DETAILED DESCRIPTION OF A PREFERRED EMBODIMENT The present induction well logging tool, useful duπng momtonng while drilling, logging while dnllmg and wireline applications, compnses a pπmary magnetic field transmitter, a receiver of the magnetic field induced by eddy currents in the investigated formation, a data acquisition and control system to manage the inductive logging tool's electronics operations, and to collect and process data A transmitter incorporates an oscillator, a power amplifier dπven by the oscillator and a transmitting antenna The receiver electronics compnse an induction antenna and input amplifier connected m senes Such downhole tool applications employ induction coils for both receiver and transmitter antennas The instrument structure provided by the present invention enables increased stability and accuracy m an induction wellbore logging tool and its operational capabilities, which, in turn, results in better quality and utility of wellbore data acquired dunng logging The features of the present invention are applicable to improve the structure of a majonty of known induction tools, those for example, designed and developed by Baker Atlas of Houston, Texas These induction tools include Baker Atlas induction tool model numbers 1507, 1515 and 1520 The induction logging tool modules inherently manifest a stray capacitance Stray capacitive coupling between the source of a time varying electnc field and a receiver anangement creates significant systematic ercors depending on the adjoining tool environment and temperature The source of the time varying electπc field includes the entire set of transmitter coils and cables connecting these transmitter coils to the respective dnving transmitter electronics The receiver anangement typically consists of a set of receiver coils and cables connecting these coils to signal conditioning amplifiers The apparatus of the present invention provides a solution to the stray capacitance coupling problem The preferred structure compπses a symmetπcal lv shielded split coil transmitter and a bucking coil In a preferred embodiment, the apparatus of the present invention provides a three axis three-coil array structure wherein the mam transmitter coil compπses two symmetrical coils wound on a single coil form and a buck g coil electπcally connected between them The apparatus of the present invention also provides a structure for symmetrically shielding the transmitter array, which maximally cancels displacement currents induced in the shield and enables minimization of the current return. In a preferred embodiment, the symmetncal shield compnses a feed through pipe as shown m Figure 4 Conventional applications have utilized asymmetncal induction coil arrays Such asymmetncal induction coil arrays result m the necessity of asymmetncal shielding configurations that tend to create significant current returns in the transmitter dnvmg source coil, wmng and circuitry In conventional tool designs, this current returns in the transmitter braid wires m the tool electronics and m the feed through pipes used to carrying interconnecting wires through the tool The present invention solves problems encountered m conventional tools Typically, conventional induction tools with feed through capabilities suffer from two major problems referred to as the "galvanic" dnven interference problem and the "induction" dπven interference problem The galvamc problem is caused by a potential difference between the tool upper transmitter housing and the tool low er receiver housing The potential difference between the transmitter and receiver housings is the result of multiple causes withm the tool Such causes, include, for example, the difference in electncal ground potentials between housings; upper and lower housings coupling through the power transformers connected to the common AC source; capacitive coupling between the electronic switching transmitter power supply and the coil driving amplifiers in the pressure housing and unshielded electrical field irradiated by transmitter coils. When a conventional tool operates in a conductive adjoining environment (i.e., borehole fluid), the potential difference between the transmitter and receiver housings creates a cunent flowing between the transmitter and receiver housings. The current flows in the borehole fluid in close proximity to the mandrel sensor section sleeve contaimng the receiver and transmitter coils. This induced current exhibits both the frequency and phase of the transmitter coil voltage, thus, the induced current generates a magnetic field inducing error voltage in the receiver coil which will be in-phase with transmitter primary magnetic field and the receiver signal to be measured. This type of error can be difficult to discriminate and remove once it has combined with the received signal. One may reduce this induced in-phase error by using heavy, low impedance feed through pipe connections between metal housings with sufficient shielding of the feed through system communication wires. Even though this solution is somewhat effective, it's problematic, due to coil construction diameters versus tool diameter and because of the "induction" interference problem, discussed below. The induction problem exists in induction instruments where the upper and lower transmitter and receiver housings are connected by such a low impedance wire or feed through pipe during tool operations in the conductive borehole. In the borehole filled with conductive fluid the magnetic field of transmitter coils induces currents flowing in a conductive parasitic loop as follows: upper housing - feed through pipe - lower housing - conductive fluid and back to the upper housing. This parasitic current loop, in turn, induces high error voltages in the receiver coil. This parasitic current loop occurs due to a complex inductive coupling between the receiver input coil, the parasitic loop and feed through pipe. This "induction" problem is the most severe for transverse magnetic measurements and is less severe in coaxial measurements. Experiments show that in some conductive boreholes the errors can reach up to thirty percent (30%) and more in arrays measuring transverse or radial magnetic field components. The present invention provides a solution to the induction problem by providing an apparatus having an electπcallv insulator or opening to create an interruption in the conductive parasitic loop The insulator or opening interrupts the induced cunent flowing in the parasitic conductive loop The parasitic conductive loop is interrupted or opened by introducing a high impedance separation, a highly-resistive or an insulator mateπal between the receiver electronics chassis and the receiver mandrel housing which is in contact with a conductive external borehole fluid The parasitic inductive loop may also be interrupted by insertion of an msulator between the feed through pipe and the receiver electronics The msulator separates the feed through pipe from the receiver electronics thereby interrupting the parasitic inductiv e current loop The "gaivanic" problem is partially attπbutable to the difference in ground potential Ground potential difference is substantially reduced by the structure of the present invention by electncal grounding only end of the tool electronics and leaving the other end floating, that is, grounding only either the receiver electronics or the transmitter electronics m the tool In a prefened embodiment the receiver end of the tool is floating since the receiver is the most noise sensitive element in the tool In an alternative embodiment, both ends are floating. In a preferred embodiment, the transmitter, receiver and galvanic electrodes are electrically isolated from each other Pnor systems have provided for frequency dependent electncal isolation in the transmitter section through use of a capacitor. See, for example, U.S. Patent No. 5,452,761 by Beard et al. The capacitor solution, however, sacnfices shielding at lower transmitter frequencies and enables induction errors, discussed above, at higher frequencies Moreover, the capacitor solution assumes that higher frequency information is less important for overall tool performance As it turns out, this assumption is not valid in the transverse induction logging tools because of the radial coil array configurations utilizing higher frequencies having greater susceptibility to this effect and the techmcal requirements for dual frequency measurements which render the conventional capacitor solution inadequate The present invention provides a novel solution to eliminate the problem without sacπficmg higher frequency content In the present invention, symmetncal coils and shielding reduce the effect of high frequency components which eliminate the need for the capacitor for "shorting" to ground of high frequency signals The receiver/feed through pipe separation or insulator, is connected in close proximity to the receiver signal conditioning amplifiers, at the most noise sensitive section of the measuring tool. Galvanically and electrically insulating the feed through pipe from the receiver electronics section enables interruption of induced currents and enables successful suppression of these enors. In a preferred embodiment, the separation impedance between the receiver section and the outer borehole environment is preferably a minimum of 10 kOhms in the usual operating frequency range. There are however, a wide range of impedances which can be controlled and selected to minimize currents and errors in accordance with specific operating frequencies and conditions. The invention will now be described in more detail and by way of example with reference to the accompanying drawings. Figure 1 schematically shows a wellbore 1 extending into a laminated earth formation, into which wellbore an induction logging tool as used according to the present invention has been lowered. The wellbore in Figure 1 extends into an earth formation which includes a hydrocarbon-bearing sand layer 3 located between an upper shale layer 5 and a higher conductivity than the hydrocarbon bearing sand layer 3. An induction logging tool 9 used in the practice of the invention has been lowered into the wellbore 1 via a wire line 11 extending through a blowout preventor 13 (shown schematically) located at the earth surface 15. The surface equipment 22 includes an electric power supply to provide electric power to the set of coils 18 and a signal processor to receive and process electric signals from the receiver coils 19. Alternatively, the power supply and/or signal processors are located in the logging tool. The relative orientation of the wellbore 1 and the logging tool 9 with respect to the layers 3, 5, 7 is determined by two angles, one of which θ as shown in the Figure 1. For determination of these angles, see, for example U.S. Patent No. 5,999.883 by Gupta, et al. The logging tool 9 is provided with a set of transmitter coils 18 and a set of receiver coils 19, each set of coils 18, 19 being connected to surface equipment 22 via suitable conductors (not shown) extending along the wire line 11. Each set of coils 18 and 19 includes three coils (not shown), which are arranged such that the set has three magnetic dipole moments in mutually orthogonal directions, that is, in x, y and z directions. The three-coil transmitter coil set transmits T x , T γ and T z . The receiver coil receives R , R γ and R z plus the cross components, Rχγ ; Rxz and R Z γ. Thus, coil set 18 has magnetic dipole moments 26a, 26b, 26c, and coil set 19 has magnetic dipole moments 28a, 28b, 28c In a preferred embodiment the transmitter coil set 18 is electncally isolated from the receiver coil set 19 In an alternative embodiment, each coil in transmitter coil set 18 electπcally isolated from each other and each coil in receiver coil set 19 electπcally isolated from each other The coils with magnetic dipole moments 26a and 28a are transverse coils, that is they are oπented so that the magnetic dipole moments are onented perpendicular to the wellbore axis, whereby the direction of magnetic dipole moment 28a is opposite to the direction of magnetic dipole moment 26a Furthermore the sets of coils 18 and 19 are positioned substantially along the longitudinal axis of the logging tool 9 As shown in Figure 2A, conventional induction logging tools provide a single transmitter and receiver coil that measure resistivity m the honzontal direction In the conventional hoπzontal mode, as shown m Figure 2 A. the resistivities of adjacent high resistivity sand and low resistivity shale layers appear in parallel, thus the resistivity measurement is dominated by low resistivity shale As shown m Figures 1 and 2B, in the present invention a transverse coil is added to measure resistivity m the vertical direction. In the vertical direction, the resistivity of the highly resistive sand and low resistivity shale are appear m seπes and thus the vertical senes resistivity measurement is dominated by the resistivity of the highly resistive sand For ease of reference, normal operation of the tool 9, as shown m Figures 1 and 2B, will be descnbed hereinafter only for the coils having dipole moments m the x-direction, i.e dipole moments 26a and 28a During normal operation an alternating current of a frequency fi is supplied by the electπc power supply of surface equipment 22 to transmitter coil set 18 so that a magnetic field with magnetic dipole moment 26a is induced in the formation In an alternative embodiment, the frequency is swept through a range f \ through f 2 This magnetic field extends into the sand layer 3 and induces a number of local eddy cuπents in the sand layer 3 The magnitude of the local eddy currents is dependent upon their location relative to the transmitter coil set 18. the conductivity of the earth formation at each location, and the frequency at which the transmitter coil set 18 is operating In pπnciple the local eddy currents act as a source inducing new currents, which again induce further new currents, and so on The currents induced into the sand layer 3 induces a response magnetic field m the formation, which is not in phase with the transmitted magnetic field, but which induces a response current m receiver coil set 19. The magmtude of the current induced in the sand layer 3 depends on the conductivity of the sand layer 3, the magnitude of the response current in receiver coil set 19. The magmtude also depends on the conductivity and thereby provides an indication of the conductivity of the sand layer 3 However, the magnetic field generated by transmitter coil set 18 not only extends into sand layer 3. but also in the wellbore fluid and m the shale layers 5 and 7 so that c rents in the wellbore fluid and the shale layers 5 and 7 are induced. Turning now to Figure 3, a schematic diagram of the preferred three-coil anay structure is depicted, compnsmg a split-coil transmitter and a buckmg coil As shown m Figure 3. in a preferred embodiment a symmetπcal transmitter-bucking coil wiπng is provided instead of the traditional coil wiπng The transmitter coil is equally divided into a first transmitter coil 30 and a second transmitter coil 32 A bucking coil 33 is electπcally connected in between the first transmitter coil 30 and the second transmitter coil 32 with buckmg coil wire extensions 34 and 35 in between first transmitter coil 30 and a second transmitter coil 32 The same configuration can be utilized for an array whether compnsing smgle or multiple transmitters and differential receivers (see, for example, the Baker Atlas 1507 and 1515 well logging instruments). In a preferred embodiment, a symmetrical wiring is utilized, in a preferred point of symmetry associated with either the center tap of the transmitter coil driver, or with the signal ground of the receiver mput pre-amplifier. In both cases, the shielding and routing wire reactances m cables connecting the coils are symmetncal with respect to both coils and the connection point, coming from the shields through routing wires and being already canceled or significantly suppressed at the pre- amplified input. Moreover, this arrangement is less sensitive to the lengthy wires routed along the tool and the diameter and conductivity of a feed through pipe containing the interconnection wiπng As shown m Figure 4 the symmetπcal shielding of the three-coil arrav enables minimization of the current return into the transmitter or receiver thereby introducing errors into the collected data samples The receiver coil 19 is shown within shield 40 Shield 40 is attached to feed through pipe 41 at point 42 Bucking coil 33 is shown within shield 44 Shield 44 is attached to feed through pipe 41 at point 45. Transmitter coil 18 is shown with shield 46 Shield 46 is attached to feed through pipe at point 37 Power amplifier 43 balanced outputs 47 and 48 dπve transmitter coil 18. As shown in Figure 5, the return cunent, IT sums to approximately zero m the preferred embodiment of the mvention. As shown in Figure 4, the receiver stray capacitance associated with the receiver coil, the receiver proximate feed through pipe, and the receiver wiπng stray capacitance is represented by capacitors 60 and 61 The cunent flowing m association with the receiver stray capacitance is represented by currents I RI 62 and I R ? 64 respectively The buckmg stray capacitance associated with the buckmg coil, the buckmg coil proximate feed through pipe, the wiπng and other sources of stray capacitance is represented by capacitors 65 and 66 The cunent flowing m association with the buckmg coil stray capacitance is represented by cunents I BI 67 and Iβ 2 68 respectively The mam transmitter stray capacitance associated with the mam transmitter coil, the mam transmitter proximate feed through pipe, and the mam transmitter wiπng stray capacitance is represented by capacitors 71 and 72. The cunent flowing m association with the transmitter stray capacitance is represented by currents I M ι 69 and I M 70 respectively. The sensor construction structure of the present invention provides cancellation for a summation current I y of approximately zero, thereby reducing the error attnbutable to the induced current induction problem. Turning now to Figure 6 A, a schematic representation of a preferred embodiment of the shielding, grounding and isolation scheme of the present mvention is illustrated. In a preferred embodiment the receiver 19 electronics is electncally isolated and insulated from the conductive pressure housing 79 The exteπor of the conductive pressure housing is m contact with the conductive wellbore fluid Electncal isolation of the receiver interrupts the induction current loop and substantially reduces the error induced into the receiver signal caused by induction currents flowmg in conventional systems. In a prefened embodiment the analog ground for the mam transmitter section 86 is connected to the conductive pressure housing 79 compnsmg for example. CuBe pipe The analog ground for the acquisition receiver electronics is preferably separated from the conductive pressure housing 79 by a high impedance in the operating frequency range, for example alOO kOhm resistor 83 or capacitor. This impedance, however, is preferably controlled to maximally reduce induced currents and associated enors. In an alternative embodiment, as shown in Figure 6B, the receiver electronics electncal ground is isolated by controlled high impedance from the conductive pressure housing and the transmitter electronics ground is electrically connected to the pressure housing. In another alternative embodiment, as shown in Figure 6C, both the receiver and transmitter electronics are electronically isolated by high impedance from the conductive pressure housing. In another embodiment, as shown in Figure 10, a galvanic electrode and a current source are provided on the same mandrel and which are electrically isolated from the induction transmitter and receiver. Turning now to Figure 7, an illustration of the settling time due to transient response 91 required during conventional frequency switching is depicted. Turning now to Figure 8, in a prefened embodiment, a sweeping frequency oscillator is provided that reduces transient response 91 and therefore requires substantially less settling time, thereby providing more time for data acquisition and stacking of more data samples. The conventional tool arrangement does not have to be reconfigured to accommodate the sweep oscillator as the majority of the electrical connections remain the same, including the synchronization loop and associated circuitry. Sweeping the transmission frequency does not prohibit dual frequency measurements as used in transverse induction logging instruments, in part due to the practical absence of transient time switched processes in the electronics. The absence of transients is useful in applications where an extremely short time is available for generation and measurement of each frequency-pair signals. Turning now to Figure 9, a schematic representation of a preferred sensor stability verification loop is illustrated. As shown in Figure 9, power amplifier 100 accepts verification tone reference signal 113 as input to the transmitter coil set 18 (coil set 18 comprising x, y and z-axis coils shown having magnetic dipole moments 26a, 26b and 26c as shown in Figure 1). When the switch 104 is in a first position and connected to node 107, the tone is coupled to the transmitter coils is reference loop 103 which senses the level of the transmitted field from transmitter coil set and sends the received signal to the transmitter reference channel 109 which is sent to processor 111 and subsequently sent to surface via telemetry 112. During logging, the reference signal is recorded to track changes in the transmitter current enabling subsequent removal of the effects of changes in the transmitter cunent on the received signal during logging. In a third position, switch 104 connects with node 105 wherein the signal goes through element 114 having a vaπable phase shifting impedance which couples the signal from the transmitter coil 101 through loop 103 into the receiver coil set 19 (coil set 19 compnsmg x, y and z-axis coils shown having magnetic dipole moments 28a, 28b and 28c as shown in Figure 1) Element 114 can be selected to induce a desired phase angle shift into the signal in order to measure both quadrature and real component of the signal where phase reference is with respect to the transmitter magnetic field In a second position, switch 104 is connected without the loss element, thus there is no loss so that the lossy and non-lossy signals can be compared This structure enables collection of quadrature sensor stability venfication data for compaπson to the quadrature component of the logging data The quadrature data is significant because it is less affected by the bore hole effects Thus the quadrature venfication signal can be used to remove errors and effects m the quadrature signal to enable more accuracy m the in-phase and out of phase data acquired dunng logging K is the ratio of the number of turns in reference coil 103 winding M B to the number of turns M τ m the transmitter coils 101 is small, for example 1/34 The voltage on the smgle loop 103 V B is the voltage m the transmitter coil 103 V τ /K The reflected impedance Zioad -eflected d e to the single coil calibration loop 103 is equal to (K ) (Z B ) where ZB is the impedance of the single loop 103 The total transmitter impedance is eual to Z τ + Zioad j -eflected is 1/34 in a preferred embodiment, therefore K is small causmg Zι oa _refiec ed to be small Thus, the inductance on the transmitter does not change appreciably when switching between the first, second and third positions Turning now to Figure 10, illustrates an alternative embodiment of the invention compnsmg the induction tool along with a galvamc electrode and current source on the same mandrel ith the induction transmitter 18 and receiver 19 As shown m Figure 10 galvanic electrodes 120 and 121 are housed on mandrel 130 along with induction transmitter 18 and induction receiver 19 In this configuration the galvanic electrodes 120 and 121 perform lateral or differential measurements The galvamc frequency range is preferably 1Hz to 1 kHz. but not exclusive of other frequency ranges which are acceptable The mduction frequency range is from lkH to 5Mz, but not exclusive of other frequency ranges which are acceptable Preamp 110 has ground 131 and provides an output signal to an analog to digital converter 123 which is electncally isolated from mam controller 111 by capacitive and galvanic isolator 125 Preamp 124 has ground 132 and provides an output signal to an analog to digital converter 128 which is isolated from mam controller 111 by capacitive and galvanic isolator 126. In a preferred embodiment, ground 131 and 132 are isolated from the pressure housing In an alternative embodiment ground 131 is electπcally connected to the pressure housing and ground 132 is isolated from the mam housing In an alternative embodiment ground 132 is electncally connected to the mam pressure housing and ground 131 is isolated from the mam housing Turning now to Figure 1 1, an alternative embodiment of the invention is shown wherein galvanic electrode 120 is located on the mandrel with the induction tool and galvanic electrode 121 is located at infinity with respect galvanic electrode 120, to facilitate performing normal galvanic measurements

Claims: What is claimed is: 1 A induction logging tool for measunng the properties of a geological formation adjacent a bore hole compnsmg a transmitter having an electncal ground, a receiver having an electπcal ground, and a controlled impedance isolating the transmitter electπcal ground from the receiver electncal ground for reducing cunent flow between the transmitter and the receiver 2 The logging tool of claim 1 further compnsmg a galvanic electrode having an electπcal ground, the galv anic electrode further compnsmg a controlled impedance isolating the galvanic electncal ground from the transmitter electncal ground for reducing current flow between the transmitter and the galvanic electrode The logging tool of claim 1 further compnsmg: a galvamc electrode having an electncal ground, the galvamc electrode further compnsmg a controlled impedance isolating the galvamc electπcal ground from the receiver electncal ground The logging tool of claim 1 further compnsmg a galvanic electrode having an electπcal ground, the galvanic electrode further compnsmg a controlled impedance isolating the galvanic electπcal ground from the receiver electπcal ground and transmitter electπcal ground The logging tool of claim 3 further compnsmg a galvamc current source having an electncal ground, the galvanic current source further compnsmg a controlled impedance isolating the galvamc current source electncal ground from the galvamc electrode electπcal ground 6 The logging tool of claim 4 further compnsmg a galvamc current source having an electncal ground, the galvamc current source further compnsmg a controlled impedance isolating the galvamc current source electncal ground from the galvanic electrode electπcal ground. 7 A logging tool as m one of claims 1 - 6 wherein the controlled impedance compπses a ten Kilo ohm resistor 8 The logging tool of claim 1 further compnsmg an electπcal insulator for electncally isolating the receiver from the well bore. 9 The logging tool of claim 1 further compnsmg a feed through pipe for housing electncal wires further compnsmg an msulator electncally insulating the feed through pipe and the receiver. 10. A induction logging tool for measuring the properties of a geological formation adjacent a bore hole comprising: a transmitter comprising a split-coil; and a receiver. 11 The apparatus of claim 10, wherein the split-coil transmitter compπses symmetrical coils. 12. The apparatus of claim 1 1, wherein the transmitter further compnses a buckmg coil interposed between the split transmitter coils. 13 The apparatus of claim 12 further compnsmg a symmetπcal spht-coil transmitter shield. 14 The apparatus of claim 13 further compnsmg a buckmg coil shield. A logging tool for measunng the electncal properties of a geological formation adjacent to a borehole compnsmg: a transmitter; a receiver; and a venfication winding for coupling a signal into the receiver coil The tool of claim 15, further compnsmg a phase shifting element m the venfication winding to mutually couple a phase shifted venfication signal into the receiver coil A induction logging tool for measunng the properties of a geological formation adjacent a bore hole compnsmg a multi-component transmitter compnsmg an λ, y and z-axis transmitter coil, a multi-component receiver, further compnsmg an x, y and z-axis receiver coil; and a controlled impedance electncally isolating the x, y and z-axis transmitter coils from the x, y and z-axis receiver coils. The logging tool of claim 17 further compnsmg a controlled impedance electπcally isolating the λ. y and z-axis receiver coils from each other The logging tool of claim 17 further compnsmg a controlled impedance electπcally isolating the \. y and z-axis transmitter coils from each other The logging tool of claim 17 further compnsmg a galvanic electrode; and a current source The logging tool of claim 20 further compnsmg a controlled impedance electncally isolating the galvanic electrode from the cunent source The logging tool of claim 21 wherem the controlled impedance isolating the galvamc electrode from the cunent source further isolates the galvamc electrode and cunent source from the transmitter x, y and z-axis coils The logging tool of claim 21 wherein the controlled impedance isolating the galvamc electrode from the cunent source further isolates the galvanic electrode and cunent source from the receiver x. y and z-axis coils A induction logging tool for measunng the properties of a geological formation adjacent a bore hole compnsmg a transmitter, a receiver, a housing for traversing the bore hole, the housing containing the transmitter and receiver; and an insulator for electncally isolating at least one of the either the receiver or the transmitter from the housing The induction logging tool of claim 24 further compnsmg a galvanic electrode contained in the housing A induction logging tool for measunng the properties of a geological formation adjacent a bore hole compnsmg a transmitter having an electπcal ground, a receiver having an electπcal ground. a housing containing the transmitter and for traversing the bore hole, the receiver ground and the transmitter ground electncally isolated from the housing; and an electπcal connection for electπcally connecting one of either the receiver electπcal ground or transmitter electπcal ground to the housing The induction logging tool of claim 26 wherein the receiver electπcal ground and the receiver electπcal ground are electπcally connected to the housing The induction logging tool of claim 26 wherein the both the receiver electπcal ground and the receiver electπcal ground are electπcally isolated from the housing The induction logging tool of claim 24 further compnsmg. a sweep frequency oscillator for continuous formation response sampling at a rate sufficient for appropπate data stacking.

Inventors: CROSSKNO MICHAEL S, FANINI OTTO N, FORGANG STANISLAV W, CROSSKNO, MICHAEL, S., FANINI, OTTO, N., FORGANG, STANISLAV, W.
Applicants: BAKER HUGHES INC, BAKER HUGHES INCORPORATED
Application year: 2000
Main classification: G01V3
IPC codes: G01V3