• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    In some embodiments, an apparatus and system, as well as methods, may include operating a transmitting antenna and receiving antenna as equivalent dipole dipoles, wherein the inclined dipoles provide a selection of equivalent angles of inclination for at least one of the transmission antenna or the receiving antenna. An additional activity may include receiving signals from the receiving antenna disposed in a geological formation, the signals being intended to be inverted to obtain at least one of the resistivity or dielectric constant properties of the geological formation at a selected depth. of investigation, the depth being determined by the selection of the equivalent inclination angles and the weighting with previously calculated integrated radial sensitivity signal data. Additional methods, apparatus, and systems are disclosed.
    公开号:FR3035146A1
    申请号:FR1651790
    申请日:2016-03-03
    公开日:2016-10-21
    发明作者:Wei-Bin Ewe；Burkay Donderici；Glenn A Wilson；Martin Luis Emilio San
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    [0001] APPARATUSES, METHODS, AND SYSTEMS FOR MEASURING TRAINING PROPERTIES BACKGROUND [0001] Understanding the structure and properties of geological formations can reduce the cost of drilling wells for oil and gas exploration. Measurements are typically made in a borehole (ie, well depth measurements) to obtain this understanding. For example, the measurements can identify the composition and material distribution surrounding the well depth measurement device. To achieve such measurements, a variety of sensors and mounting configurations can be used. These devices include antennas that are used to provide Nuclear Magnetic Resonance (NMR) measurements, and antennas to provide resistivity measurements, as well as others. Measurements made by conventional high frequency dielectric tools can be used to determine the formation dielectric constant (also called relative permittivity) and the resistivity at a depth of investigation ("Depth of Investigation" or D01) which depends on training characteristics. However, these tools tend to operate in a single polarization mode (ie, lateral firing mode), and thus the DOI is fixed. BRIEF DESCRIPTION OF THE DRAWINGS [0003] FIGS. 1 and 2 are side views of antenna arrays, with equivalent magnetic dipoles, mechanically and electrically inclined, respectively, which can be oriented at an angle θ with respect to the longitudinal axis of the antenna. associated casing, according to various embodiments of the invention. [0004] FIGS. 3 and 4 are graphs indicating the real and weighted average responses, respectively, for the calculated integrated radial sensitivity 1 3035146 of an antenna array in a formation having a dielectric constant Er = 10 and a resistivity R = 10 Om, according to various embodiments of the invention. [0005] FIGS. 5 and 6 are graphs indicating the actual and weighted average responses, respectively, for the calculated integrated radial sensitivity of an antenna array in a formation having a dielectric constant Er = 25 and a resistivity R = 1 Om according to various embodiments of the invention. [0006] Fig. 7 is a flowchart for a method of constructing a weight conversion table, according to various embodiments of the invention. [0007] FIG. 8 is a flowchart for a method for inverting measurements obtained from a dielectric tool constructed and put into operation according to various embodiments of the invention. [0008] Fig. 9 is a block diagram of a logging system according to various embodiments of the invention. Figure 10 is a flowchart illustrating methods of constructing a weight table, and applying weight values to received data to obtain a desired DOI, according to various embodiments of the invention. Figure 11 illustrates an illustrative drill-down system according to various embodiments of the invention. Fig. 12 illustrates an illustrative drilling installation system according to various embodiments of the invention.
    [0002] DETAILED DESCRIPTION [0012] In order to dynamically control the DOI, additional information, including data obtained from other polarization modes, may be used. To overcome the challenges noted above, as well as others, many embodiments include a dielectric tool that can determine the dielectric constant (also referred to as relative permittivity) and the resistivity of the formation at a substantially constant DOI, and controllable, using different antenna polarizations. Additional polarization modes can be obtained mechanically, or electronically. Antennas that can operate in different polarization modes can be represented by an equivalent magnetic dipole inclined with respect to the tool axis. For example, Figures 1 and 2 are side views of antenna arrays 10, equivalent magnetic dipoles, inclined mechanically and electrically, 100, 200, respectively, which can be oriented at an angle 0 relative to the longitudinal axis 110 of the associated housing 120, according to various embodiments of the invention. Referring to FIG. 1, it can be seen that the mechanical embodiment of additional polarization modes may comprise the physical movement of one or more antennas in a network 100 at an angle θ with respect to longitudinal tool axis. Here, the transmitting antenna Tx1 and the receiving antennas R1, R2, R3 are represented in operation in a conventional lateral firing mode. However, after mechanical rotation at the angle θ, perhaps using an actuating mechanism 130 attached to the housing 120 and including one or more of electric motors, hydraulic members, or solenoids, they can operate in An inclined mode, which adjusts the DOL In the figure, the inclined mode for the transmitting antenna Tx1 and the receiving antennas R1, R2, R3 is shown using dashed lines. In Figure 2, a network of inclined magnetic dipoles 200 consists of a transmitter (Tx) and two receivers (R1 and R2) having an inclination angle 0 relative to the axis of 'tool. When the tilt angle θ = 90 ° (i.e., the tilt angle is perpendicular to the longitudinal axis 110, as shown by the dashed arrows), the network 200 can operate in the lateral lateral. In some embodiments, a single receiver (eg, R1) may be used. In this case, the phase difference can be measured from the transmitter Tx1 to the receiver R1, and the amplitude ratio can be measured as the ratio of the voltage or current of the transmitter Tx1 to the signal of the receiver R1. Performing measurements in this manner, using a single transmitter-referenced-receiver combination, can provide sufficient resolution for a number of well-depth investigation tasks. It should be noted that obtaining, electronically, additional polarization modes can be accomplished by using antennas of non-symmetrical (eg, rectangular) shape 210, or symmetrical antennas, such as antenna configurations. multi-source circular cavities, or square antenna configurations, the shapes of which are well known to those of ordinary skill in the art. Figures 3 and 4 are graphs 300, 400 indicating the actual and weighted average responses, respectively, for the integrated radial sensitivity ("Integrated Radial Sensitivity" or IRS) calculated from an antenna array 20 in a formation having a dielectric constant Er = 10 and a resistivity R = 10 Qm, according to various embodiments of the invention. In this example, five different inclination angles: 0 = 0 °, 30 °, 45 °, 60 ° and 90 ° are considered in the calculation. In the figure, for each inclination angle, the IRS of the ratio between the receiver R1 and R2 in response to the transmitter Tx1 is calculated and plotted. It is observed that the angle 0 = 0 ° produces the deepest IRS, which is reduced as the angle 0 increases towards 90 °. In FIG. 4, the IRS is obtained from the weighted average of the integrated radial sensitivities of the five different inclination angles θ using equation (1): 4 3035146 Ei wiIRS (6, i) IRS weighted =,. (1) L i wi Two different sets of weights (indicated by solid and dotted lines, respectively) have been applied in graph 400 to illustrate that the IRS can be controlled using different weights. Figures 5 and 6 are graphs 500, 600 showing the actual and weighted average responses, respectively, for the calculated integrated radial sensitivity of an antenna array in a formation having a dielectric constant Er = 25 and a resistivity R = 1 μm, according to various embodiments of the invention. In this example, the results are similar to those shown in Fig. 3, but the background medium has a dielectric constant which is twice that of Fig. 3, and a resistivity which is one-tenth of the value of Figure 3. Here, the IRS of five different tilt angles are also calculated and plotted. In FIG. 6, the IRS curves for different weights are again shown, being calculated from the weighted average of the five IRS values obtained in FIG. 5, using equation (1). ). Once again, it is demonstrated that the resulting IRS can be controlled using different weight sets, indicated by the solid and dotted lines. The weights obtained from different values of the DOI can then be applied to the measurement data and formation property information can subsequently be obtained by inversion. Figure 7 is a flowchart for a method 711 of constructing a weight conversion table, according to various embodiments of the invention. Weights can be determined during inversion or interpolated from a previously calculated conversion table. The conversion table can be constructed by response simulation (s) over a range of dielectric constant and resistivity, and by calculating weights other than DOI by matrix inversion. Thus, in some embodiments, the method 711 begins at block 721 and continues at block 725 with obtaining background training properties from a list - perhaps for a game. depths (e.g., resistivity 0.1 to 10,000 ohms * m, dielectric constant 1 to 150). The list can exist as a large table containing any expected combinations of data. [0027] The method 711 can continue at block 729, with the simulation of the network activity in the formation, to determine the resulting received signal. The method 711 can continue to block 733 with the calculation of the radial sensitivity of the network, using the signals resulting from the activity at block 729. The radial sensitivity can be calculated by considering a medium consisting of two or more , layers separated by cylindrical boundaries, and varying the size of the cylinders. The radial sensitivity can alternatively be calculated by an approximation of Born, although this method may be less accurate for the operating range of a dielectric tool. Both methods of calculating radial sensitivity are well known to those of ordinary skill in the art, and are documented in numerous publications. In block 737, method 711 may include a determination of weights for a desired DOI, perhaps using an approximation method (for example, through the plotting and inspection of results, such as those shown in Figures 3 and 5), or a conventional approach to minimize a desired convergence value, such as finding a set of weights to achieve the desired DOI at a desired IRS. Mathematical optimization algorithms that are well known to those of ordinary skill in the art can be used to accomplish this task. The method 711 may proceed to block 741, iterating blocks 725-737 for each combination of properties and depths 3035146 which are included in the block 725 list. When the list has been exhausted, the Method 711 can be concluded at block 745. [0031] FIG. 8 is a flowchart for a method 811 of reversing measurements obtained from a dielectric tool constructed and operated according to various embodiments of the invention. Here the diagram continues the implementation of various embodiments, after the weights determined as part of the activities shown in Fig. 7 have been determined. At this point, the weights, perhaps stored as a conversion table, may be used in conjunction with the inversion of data obtained from a well depth tool, such as a dielectric tool. In this method 811, the initial training model is first inverted from the measurement data. Then, based on the initial training model, the weights can be interpolated from the conversion table and used to average the responses of the measured data on different modes of polarization. Then, average data can be used to obtain new training information, and to control the convergence of the training model. Weight recovery procedures from the conversion table and average responses are iterated until the training model converges. Thus, in some embodiments, the method 811 starts at block 821, and continues at block 825 with obtaining initial inverted formation information using initial measurement values obtained from a tool in progress. well depth. These initial values may take the form of antenna signals, such as those illustrated in FIG. 3 or 5. [0034] The method 811 may continue to block 829 with the application of signal weights (for example, for this training, at the desired DOI, with weights that give the highest sensitivity). Depending on the data that has been measured, method 811 may include, in block 833, the interpolation of the weight values in the conversion table. The signal weighting can be accomplished using equation (2): SW = W1 * S1 + W2 * S2 + ... (2) where SW is the weighted signal, W1 is the first weight, S1 is the first signal, W2 is the second weight and S2 is the second signal, and so on. Equation (2) includes two terms of average, which is a useful number, however, if more signals are available, more weighting terms can be used. Signals may take the form of voltages, currents, phases, amplitudes, phase differences or amplitude ratios, as well as combinations thereof. The average of received signal values can be made before weighting values are applied or after weighting values are applied. The method 811 may further include, in block 833, iterative interpolation at different inspection depths to obtain the desired DOI. If the table already contains weight values for the DOI in question, the interpolation at block 833 can be avoided. The method 811 may continue to block 837, to include training information refresh 20 by inverting the weighted versions of the signals (determined at block 829, based on the original signals obtained at block 825) to determine training properties. This determination may include the mapping of measured signals, such as phase difference and amplitude ratio, to formation properties, such as resistivity and dielectric constant. For example, after the resistivity and the dielectric constant are obtained, petrophysical parameters, such as water saturation, can be calculated. This process is well known to those of ordinary skill in the art, and documented in a number of publications. At block 841, method 811 may include checking the inversion results to evaluate whether different DOI property results are converging.
    [0003] This occurs when, for example, the results of activity at block 837 (e.g., formation properties) are constant across different inspection depths. When this occurs, method 811 can conclude at block 845. If, on the contrary, the results diverge (for example, formation properties determined at block 837 are not constant across different depths of inspection) this may signal an approaching transition zone, and further investigation may be useful. Thus, method 811 may include an iteration between blocks 829, 833, 837, and 841.
    [0004] Still further embodiments may be realized.  For example, Figure 9 is a block diagram of a logging system 910 according to various embodiments of the invention.  Referring now to FIGS. 1, 2, and 9, it can be seen that the logging system 910 can receive counting measurement data from the antenna arrays 100, 200 serving as controlled devices 970 (e.g. for mechanically or electronically tilting one or more antennas in the networks 100, 200, and for energizing them to transfer energy into the surrounding formation) and measuring devices 904 (for example, to receive signals corresponding to formation properties, such as resistivity).  The logging system 910 can thus include the networks 100, 200 operating in a wellbore.  The processing unit 902 may couple to the measurement device 904 to obtain measurements from the arrays 100, 200 and other devices, as previously described herein.  In some embodiments, a logging system 910 includes one or more of the arrays 100, 200, as well as a casing 900 (see also FIGS. 11 and 12) that can accommodate the apparatus 904, 970, as well as other elements.  The housing could take the form of a drill string tool body, or a well depth tool, as described in more detail below with reference to Figures 11 and 12.  The process unit 902 may be part of a surface workstation or may be attached to a well depth tool housing.  In some embodiments, the processing unit 902 may be housed within a housing 120, previously described herein.  The logging system 910 may include a controller 925, another electronic apparatus 965, and a communication unit 940.  The controller 925 and the processing unit 902 may be fabricated to operate the measuring device 904 to acquire measurement data, such as signals corresponding to formation resistivity measurements.  The electronic device 965 (for example, electromagnetic sensors, etc.) ) can be used in conjunction with the controller 925 to perform tasks associated with performing well depth measurements using the measuring device 904.  The communication unit 940 may include well depth communications in a drill string or a drilling operation.  Such deep well communications may include a telemetry system.  The logging system 910 may also include a bus 927 for providing common electrical signal paths between the components of the logging system 910.  The bus 927 may include an address bus, a data bus, and a control bus, each independently configured.  The bus 927 may also use common conductive lines to provide one or more of an address, data, or command, the use of which may be controlled by the controller 925.  The bus 927 may include an instrumentality for a communication network.  The bus 927 may be configured such that the components of the logging system 910 are distributed.  Such a distribution may be arranged between deep well components such as measuring device 904 and components that may be disposed on the surface of a well.  Alternatively, several of these components 3035146 may be positioned together, for example on one or more drill collars of a drill string or on a drill string structure.  In various embodiments, the logging system 910 includes peripheral devices that may include displays 955, an additional storage memory, or other controlled devices 970 that may operate in conjunction with the controller 925 or the processing unit 902.  The display 955 may display diagnostic information for the measuring device 904 based on the generated signals according to embodiments described above.  The display 955 may also be used to display one or more graphs similar or identical to those shown in FIGS. 3-6.  In one embodiment, the controller 925 may be fabricated to include one or more processors.  The display 955 may be manufactured or programmed to operate with instructions stored in the processing unit 902 (e.g. in the memory 906) to implement a user interface to manage the operation of the measurement device 904 or components. distributed within the 910 logging system.  This type of user interface can be operated in conjunction with the communication unit 940 and the bus 927.  Various components of logging system 910 may be integrated with measuring device 904 and associated housing 900 such that processing identical or similar to the methods described with respect to various embodiments herein can be performed in depth of 25 wells.  Thus, any one or more components of the measuring device 904 and / or the controlled device 970 can be attached to the housing 900 or contained therein.  In various embodiments, a machine-readable non-transitory storage device may include instructions stored thereon which, when made by a machine, cause the machine to become a machine-readable device. a particular customized machine that performs operations comprising one or more characteristics similar or identical to those described with respect to the methods and techniques described herein.  A machine readable storage device herein is a physical device that stores information (eg, instructions, data), which when stored, modifies the physical structure of the device.  Examples of a machine readable storage device may include, but are not limited to, a memory 906 in the form of Read Only Memory (ROM), Random Access Memory (RAM), a magnetic disk storage device, an optical storage device, a flash memory, and other electronic, magnetic, or optical memory devices, including combinations thereof.  The physical structure of stored instructions can be operated on by one or more processors such as, for example, the processing unit 902.  The operation of these physical structures may cause the machine to perform operations according to methods described herein.  The instructions may include instructions for causing the processing unit 902 to store measurement data, conversion tables (eg, generated by the methods of Fig. 7), and other data in the memory. 906.  The memory 906 can store the results of measurements of formation parameters or parameters of the networks 100, 200, to include gain parameters, calibration constants, identification data, etc.  The memory 906 may therefore include a database, for example a relational database.  FIG. 10 is a flowchart illustrating methods of constructing a weight table, and applying weight values on received data to obtain a desired DOI, according to various embodiments of the invention.  For starters, weight table construction methods will be described.  Thus, in some embodiments, a method 1011 for constructing a measurement data weight conversion table, to enable dynamic DOI control for resistivity or dielectric constant measurements, can begin at a time. block 1021 and continue to block 1025 to include an operation of simulating an inclined dipole antenna array in a simulated geological formation to obtain simulated signals over a predetermined range of tilt angles of equivalent magnetic dipoles and properties of the geological formation.  In some embodiments, the method 1011 may continue to include determining the integrated radial sensitivity of the array with respect to the range of tilt angles of magnetic dipoles equivalent to the block 1029.  In some embodiments, the method 1011 may continue to include the determination of weighted average values corresponding to the equivalent dipole angle range of equivalent magnetic dipoles and a desired DOI at block 1033.  The weighted average values can be obtained using a mathematical optimization process.  Thus, the activity at block 1033 may include selecting the weighted average values to provide a maximum value for the integrated radial sensitivity to the desired DOI.  In certain embodiments, the method 1011 can conclude in block 1037 with the storage of the weight values in a memory, to allow the dynamic control of DOI with respect to the resistivity or dielectric constant measurement for a geological formation. actual when accessing and applying the weight values on actual signals received by at least two actual receiving antennas disposed in a real geological formation.  The activities can be repeated over a range of inspection depths.  Thus, the method 1011 may include repeating the simulation, determining the integrated radial sensitivity of the array, and determining the weighted average values over a range of investigation depths.  That is, in some embodiments, the method 1011 may return to block 1025 from block 1037, to iterate the activities of blocks 1025, 1029, 1033, and 1037, when data is to be developed for depths of 1025, investigation, as determined in block 1041.  In some embodiments, the method 1011 may continue to block 1045 from block 1041 when a sufficient number of weighted average values have been developed and stored.  In block 1045, methods that are used to apply weight values to received data to obtain a desired DOI begin.  Thus, in block 1045, a method 1011 may include the activity of operating at least one transmitting antenna and at least one receiving antenna as equivalent dipole dipoles.  The inclined dipoles provide a selection of equivalent inclination angles for at least one of the transmitting antenna or the receiving antenna, or both.  The DOI can be selected by orienting one or more of the antennas.  Thus, the activity at block 1045 may include selecting the DOI 20 by orienting one or more transmit antennas and / or one or more receive antennas, to select any number of equivalent tilt angles.  The method 1011 may continue at block 1049 to include receiving signals from receiving antennas arranged in a geological formation, the signals to be inverted to obtain at least one of the resistivity or dielectric constant properties of the geological formation at a selected DOI, the depth determined by the selection of the equivalent inclination angles and the weighting with previously calculated integrated radial sensitivity signal data.  As noted previously (and expanded in the activities of method 1011 of blocks 1025 to 1041), a conversion table in a memory can be used to provide weight values that are applied to the signals measured by receiving antennas.  Thus, the method 1011 may continue to block 1053 to include retrieving weight values corresponding to a desired level of integrated radial sensitivity and depth to be applied to the signals, producing weighted signal data.  Often, the weight values are selected to provide the largest amplitude of response to the selected DOI.  Thus, the desired level of integrated radial sensitivity may include a maximum value.  In some embodiments, data from the look-up table may be used directly for investigative depths that have been selected and are listed in the table, or interpolated to provide a selected DOI that does not. is not listed directly in the table.  The interpolation can be an iterative process.  Thus, the method 1011 may include, at block 1071, the interpolation between weight values stored in a memory to derive weight values corresponding to the selected DOI, and the application of the weight values to the signals, producing weighted signal data.  The activity at block 1071 can thus take place according to needs.  The sensitivity level can be maintained at the selected depth, through various types of training, in some embodiments.  Thus, the activity at block 1071 may include applying weight values corresponding to a desired level of integrated radial sensitivity and depth, to maintain the desired level of integrated radial sensitivity across more than one type of training. .  The weighted values of the measured signals can be inverted to determine the resistivity and dielectric constant of the formation at a selected DOI.  Thus, in some embodiments, the method 1011 may continue at block 1057 to include the inversion of the weighted signal data to determine at least one of the resistivity or dielectric constant properties of the geologic formation.  When portions of the model are constant (i.e., self-constants), then confidence in the results increases.  Thus, when measurements are made at different selected depths of investigation, the convergence of formation properties between depths can be confirmed.  Thus, the method 1011 may comprise, at block 1061, the convergence determination of at least one of the resistivity or dielectric constant properties over a range of the DO1, as a measure of model quality.  If the convergence is confirmed, the method 1011 can continue to block 1065, to determine if another measurement cycle is desired.  If so, the method 1011 may include returning to block 1045, and iterating the activities of blocks 1045-1071.  The method 1011 can conclude at block 1069, if no further measure is desired.  On the other hand, a transition zone can be discovered, as a result of divergent formation property measurements at different depths of investigation.  Thus, if convergence is not confirmed at block 1061, method 1011 can continue at block 1075 to include determining the divergence of the at least one of the resistivity or dielectric constant properties over a range of DOI, as a measure of the existence of a training transition zone.  At this point, the method 1011 can continue to include the activity at block 1065.  Still further embodiments can be realized.  For example, as previously described herein, resistivity and dielectric constant measuring tools may be used in a Logging While Drilling (LWD) or logging tool set. well logging.  Figure 11 illustrates an illustrative drilldown cable system 1164, according to various embodiments of the invention.  Fig. 12 illustrates an illustrative drilling rig system 1264, according to various embodiments of the invention.  One or the other of the systems in FIGS. 11 and 12 can be used to control the apparatus 100, 200 for making measurements in a wellbore.  Thus, the systems 1164, 1264 may include portions of a wellbore logging tool body 1170 as part of a wellbore logging operation, or a well depth tool. 1224 (for example, a drilling operations tool) as part of a deep well drilling operation.  Turning now to Figure 11, a well may be seen during wireline logging operations.  In this case, a drilling platform 1186 is equipped with a 1188 derrick which supports a lifting device 1190.  The drilling of oil and gas wells is commonly carried out using a string of drill pipes connected together to form a drill string that is lowered through a rotary table 1110 into a borehole. well or borehole 1112.  Here, it is assumed that the drill string has been temporarily removed from the borehole 1112 to allow a drill string logging tool body 1170, such as a probe or a probe, to be lowered by a borehole. Drill cable or logging cable 1174 in borehole 1112.  Typically, the wellbore logging tool body 1170 is lowered to the bottom of the region of interest and subsequently pulled upward at a substantially constant rate.  During the upward movement, at a series of depths, the instruments (e.g., the networks 100, 200, or the system elements 910 shown in FIGS. 1, 2, and 9) included in the body tool 1170 may be used to perform measurements on underground geological formations adjacent to borehole 1112 (and tool body 1170).  The measurement data may be communicated to a surface logging facility 1192 for storage, processing, and analysis.  The logging facility 1192 may be provided with electronic equipment for various types of signal processing, which may be applied by any one or more of the system components 910 and / or a display 1196 to view the results.  Similar training evaluation data may be collected and analyzed during drilling operations (for example, during LWD operations, and by extension, sampling during drilling).  In some embodiments, the tool body 1170 includes one or more arrays 100, 200 for obtaining and analyzing electromagnetic field measurements in an underground formation through a borehole 1112.  The tool is suspended in the wellbore by a drill bit 1174 which connects the tool to a surface control unit (e.g., including a workstation 1154, which may also include a display).  The tool may be deployed in borehole 1112 on a spiral tube, attached drill stem, wired drill pipe, or other suitable deployment technique.  Referring now to Figure 12, one can see how a system 1264 can also form a portion of a drilling rig 1202 located at the surface 1204 of a well 1206.  The drill rig 1202 can provide support for a drill string 1208.  The drill string 1208 can operate to enter the rotary table 1110 to drill the borehole 1112 through the subterranean formations 1114.  The drill string 1208 may include a drive rod 1216, a drill pipe 1218, and a bottom hole assembly 1220, perhaps located on the lower portion of the drill pipe 1218.  The downhole assembly 1220 may include drill collars 1222, a well depth tool 1224, and a drill bit 1226.  The bit 1226 can operate to create the borehole 1112 by penetrating the surface 1204 and the subterranean formations 1214.  The well depth tool 1224 may include any one of a number of different types of tools, including "Measure While Drilling" (MWD), LWD, and others.  During drilling operations, the drill string 1208 (perhaps including the drive rod 1216, the drill rod 1218, and the downhole assembly 1220) can be set up. rotation by the rotation table 1110.  Although not shown, in addition, or alternatively, the downhole assembly 1220 may also be rotated by a motor (eg, a slurry engine) which is located at the well depth.  Drill collars 1222 may be used to add weight to drill bit 1226.  The drill collet 1222 may also operate to stiffen the downhole assembly 1220, allowing the downhole assembly 1220 to transfer the added weight to the bit 1226, and then to assist the bit 1226 in drilling. the penetration of the surface 1204 and the underground formations 1214.  During drilling operations, a slurry pump 1232 can pump a drilling fluid (sometimes referred to by the ordinary man of the "drill mud" art) from a sludge tank 1234 through a pipe. flexible 1236 in the drill rod 1218 and down to the drill bit 1226.  The drilling fluid may flow out of the bit 1226 and be returned to the surface 1204 through an annular zone 1240 between the drill stem 1218 and the sides of the borehole 1112.  The drilling fluid can then be returned to the sludge tank 1234, where such fluid is filtered.  In some embodiments, the drilling fluid may be used to cool bit 1226, as well as to provide lubrication for bit 1226 during drilling operations.  In addition, the drilling fluid can be used to remove subterranean drilling cuttings created by the operation of bit 1226.  Thus, it can be seen that, in some embodiments, the 1164, 1264 systems may include a drill pipe drill 1222, a well depth tool 1224, and / or a logging tool body at Drill cable 1170 for housing one or more networks 100, 200 similar or identical to the networks 100, 200 shown in Figures 1 and 2.  System components 910 in FIG. 9 may also be accommodated by tool 1224 or tool body 1170.  [0077] Thus, for the purpose of this document, the term "housing" may include any one or more of a drill pipe drill 1222, a well depth tool 1224, or a logging tool body having a drilling cable 1170 (all having an outer wall for enclosing or attaching to magnetometers, sensors, fluid sampling devices, pressure measuring devices, transmitters, receivers, acquisition logic and processing, and data acquisition systems).  The tool 1224 may include a well depth tool, such as an LWD tool or MWD tool.  The drill string tool body 1170 may include a well logging tool, including a probe or probe, for example, coupled to a logging cable 1174.  Many embodiments can thus be realized.  For example, a system 1164, 1264 may include a well depth tool body, such as a wellbore logging tool body 1170 or a well depth tool 1224 (for example, a tool body of LWD or MWD), and one or more networks 100, 200 attached to the tool body, the networks 100, 200 being intended to be constructed and operated as previously described.  Thus, with reference to FIGS. 1 to 12, it can be seen that, in certain embodiments, an apparatus may comprise a transmission antenna Tx1, and a reception antenna R1- or more than one of the one 25 or the other antenna (for example, Tx2, R2, R3, etc. ), which can be oriented at a variety of angles of polarization, or equivalently, of dipole inclination angles.  That is, a selected bias angle is electrically equivalent to a dipole inclined at an angle to the longitudinal tool axis.  For example, the equivalent dipole tilt angle for a cavity antenna can be obtained by orienting the antenna electrically, for example by changing the amplitude and / or phase of cross-source inputs. .  A loop antenna, with a single source point, can be mechanically oriented to obtain an equivalent dipole tilt angle (i.e., a selected bias angle), physically changing the angle as the plane of the antenna shape relative to the longitudinal tool axis (as shown in Figure 1).  A receiving antenna with an inclination angle θ closer to 90 degrees to the tool axis will usually have a shallower DOI than a receiving antenna with an angle of inclination e closer to 0 degree.  For purposes of this document, the "integrated radial sensitivity" or IRS of an antenna is a value that represents a certain portion of the signal that is received by an equivalent magnetic dipole receive antenna due to the response. disturbed from a given formation at a given depth.  The normalized value of the IRS varies between 0 and 1, where a value of 0.5 at a formation depth of 4 inches, for example, means that 50% of the signal received by the antenna is due to the effect of formation properties varying at depths from the surface of the formation (0 inches deep), up to 4 inches into the formation (4 inches deep) from the face of the receiver.  A brief list of several additional embodiments will now be provided.  Referring to FIGS. 1 to 12, it can be seen that in some embodiments an apparatus includes at least one transmitting antenna Tx1 and a receiving antenna R1, steerable to provide equivalent dipoles with an angle tilt selected 0; and a control device 925 for selecting the selected inclination angle of the transmitting antenna Tx1 and the receiving antenna R1, to enable acquisition of signal data by the corresponding receiving antenna R1 21 3035146 at a DOI selected for the resistivity and the dielectric constant in a geological formation.  The antennas may be constructed or controlled for the orientation to occur synchronously.  Thus, the transmission antenna Tx1 and the receiving antenna R1 can be synchronously steerable.  In some embodiments, the antennas Tx1, Tx2 and R1, R2, R3 are electrically steerable, mechanically steerable, or both.  The apparatus may include a memory for storing received signal weighting values, for adjusting a response of the antenna array for different types of formations, and different selected investigation depths.  Thus, in some embodiments, the apparatus may include a memory 906 accessible by the controller 925, the memory 906 being for storing a weight conversion table of measurement data corresponding to the angle of inclination selected e and at the selected DOI.  One or more of the antennas may comprise an electrically orientable cavity antenna, such as a square cavity antenna or a circular cavity antenna, with a multiple source capability.  For example, the antenna (s) may allow the use of a cross-source excitation signal, from top to bottom, and from left to right.  The energy from each source can be adjusted to control the polarization angle, and thus, the equivalent dipole tilt angle.  The antennas may comprise a truncated waveguide filled with dielectric material, including a rectangular cavity antenna.  Thus, in some embodiments, the transmission antenna Tx1 comprises a multi-source cavity antenna.  Some embodiments are embodied as a system.  Thus, in some embodiments, a system 910, 1164, 1264 includes a housing 900, 1170, 1224; a set of antennas Tx1, Tx2, R1, R2, R3; and a control device 925.  In some embodiments, a system 910, 1164, 1264 includes a well depth tool housing having a longitudinal axis (e.g., tool 1170 or 1224); at least one transmission antenna Tx1 and at least one receiving antenna R1 attached to the housing, the transmission antenna Tx1 and the receiving antenna R1 being synchronously steerable to provide a network of equivalent dipoles with an angle of tilt selected.  The system 910, 1164, 1264 may further include a controller 925 for selecting the selected tilt angle θ, to enable acquisition of signal data by the receiving antenna R1 corresponding to a selected DOI for at least one physical property in a geological formation in which the housing is disposed.  [0087] One or more of the antennas may comprise a cross-source antenna, including a square cavity antenna or a circular cavity antenna.  Thus, in some embodiments, the transmitting antenna (s) Tx1, Tx2, or receiving antenna (s) R1, R2, R3, or both include a square cavity antenna or a source circular cavity antenna. cross.  [0088] The system can be used in both drilling and drilling cable applications.  Thus, in some embodiments, the well depth tool housing includes one of a wire rope tool housing 1170 or a drill string tool housing 1224.  Any of the above components, e.g. networks 100, 200, or systems 900, 1164, 1264 (and each of their 25 elements) may all be referred to as "modules" herein.  Such modules may include hardware circuitry, and / or a processor and / or memory circuits, software program modules and objects, and / or firmware, and combinations thereof, as desired by The architect of networks 100, 200 and systems 900, 1164, 1264 and is suitable for particular implementations of various modes of realization.  For example, in some embodiments, such modules may be included in an apparatus and / or system operation simulation set, such as a software electrical signal simulation set, a simulation set of use and distribution of electrical energy, a set of electrical energy / heat dissipation simulation, a measured radiation simulation set, and / or a combination of software and hardware used to simulate the operation of various modes potential achievements.  [0090] It should also be understood that the apparatuses and systems of various embodiments may be used in applications other than for logging operations, and thus, various embodiments need not be limited.  The illustrations of networks 100, 200 and systems 900, 1164, 1264 are intended to provide a general understanding of the structure of various embodiments, and they are not intended to serve as a complete description of all elements and all the characteristics of the devices and systems that could use the structures described herein.  Applications that may include new devices and systems of various embodiments include electronic circuitry used in very fast computers, communication and signal processing circuitry, modems, processor modules, embedded processors. , data switches, and application specific modules.  It will be appreciated that the methods described herein with respect to FIGS. 7 and 8 and 10 need not be performed in the order described, or in any particular order.  In addition, various described activities with respect to the methods identified herein may be performed iteratively, serial, or parallel.  Activities in one process may be substituted for those of another process.  Information, including parameters, instructions, operands, and other data, may be sent and received as a carrier or carrier wave.  [0093] Following the reading and understanding of the contents of the present disclosure, the ordinary person skilled in the art will understand how a software program can be launched from a computer readable medium in a computer-based system. computer to perform the functions defined in the software program.  Those of ordinary skill in the art will further understand the various programming languages that may be employed to create one or more software programs designed to implement and carry out the methods disclosed herein.  For example, programs can be structured in an object-oriented format using an object-oriented language, such as Java or C #.  In another example, the programs can be structured in a procedure-oriented format using a procedural language, such as Assembly or C.  The software components may communicate using any of a number of mechanisms well known to those of ordinary skill in the art, such as application program interfaces or interprocess communication program techniques, including calls. remote procedure.  The teachings of various embodiments are not limited to any particular programming language or environment.  In summary, the use of the apparatuses, systems, and methods disclosed herein may provide increased gain stability over gamma ray measuring tools operating in the presence of sensor sensitivity drift, extreme temperatures, vibrations, or other environmental or design factors relating to conventional mechanisms.  These benefits can significantly enhance the value of the services provided by an operating / exploration company, helping to reduce the costs associated with time.  [0095] Current tools for depth determination of resistivity and dielectric constant wells are often not able to measure formation properties with a controllable DOI.  The present disclosure discloses apparatus, systems, and methods that permit data inversion from a dielectric tool, for example, to a desired DOI, reducing uncertainty as the DOI varies. on different training topics.  This provides consistent and accurate measurement results, and so, more customer satisfaction.  The accompanying drawings which form part of the present present, by way of illustration, and not limitation, specific embodiments in which the subject may be practiced.  The illustrated embodiments are described in sufficient detail to enable those skilled in the art to practice the teachings disclosed herein.  Other embodiments may be used and derived therefrom so that structural and logical substitutions and changes can be made without departing from the scope of the present disclosure.  The present detailed description, therefore, should not be construed in a limiting sense, and the scope of various embodiments is defined only by the appended claims, together with the full scope of equivalents to which such claims are entitled.  [0097] Such embodiments of the subject of the invention may be hereinafter individually and / or collectively referred to as "invention" simply for convenience and without intention to voluntarily limit the scope of this application. to any singular invention or any singular concept of invention if more than one is actually disclosed.  Thus, although specific embodiments have been illustrated and described herein, it should be appreciated that any arrangement calculated to achieve the same purpose may be substituted for the specific embodiments shown.  The present disclosure is intended to cover any and all adaptations or variations of various embodiments.  Combinations of the above embodiments, and other non-specifically disclosed embodiments herein will be apparent to those skilled in the art upon review of the above description.  Although specific embodiments have been illustrated and described herein, one of ordinary skill in the art will appreciate that any arrangement, which is calculated to achieve the same objective, may be substituted for the specific embodiments. represented.  Various embodiments use permutations or combinations of embodiments described herein.  It is to be understood that the above description is intended to be illustrative, not restrictive, and that the phraseology or terminology used herein is for descriptive purposes.  Combinations of the above embodiments and other embodiments will be apparent to those of ordinary skill in the art when studying the above description.  27
    权利要求:
    Claims (20)
    [0001]
    REVENDICATIONS1. An apparatus, comprising: at least one transmitting antenna and a receiving antenna, steerable to provide equivalent dipoles with a selected inclination angle; and a control device for selecting the selected inclination angle of the transmitting antenna and the receiving antenna, to enable acquisition of signal data by the receiving antenna corresponding to a selected depth of investigation for resistivity and dielectric constant in a geological formation.
    [0002]
    2. Apparatus according to claim 1, wherein the transmitting antenna and the receiving antenna are synchronously steerable.
    [0003]
    Apparatus according to claim 1, wherein the transmitting antenna and the receiving antenna are electrically steerable.
    [0004]
    An apparatus according to claim 1, further comprising: a memory accessible by the controller, the memory being for storing a measurement data weight conversion table corresponding to the selected tilt angle and the depth selected investigation.
    [0005]
    An apparatus according to claim 1, wherein the transmission antenna comprises a multi-source cavity antenna.
    [0006]
    A system, comprising: a well depth tool housing having a longitudinal axis; At least one transmission antenna and a receiving antenna fixed to the housing, the transmission antenna and the receiving antenna being synchronously steerable to provide an array of equivalent dipoles with a selected inclination angle; and a control device for selecting the selected inclination angle, for enabling acquisition of signal data by the receiving antenna corresponding to a selected depth of investigation for at least one physical property in a geological formation in which the housing is arranged. 10
    [0007]
    The system of claim 6, wherein at least one of the transmitting antenna or receiving antenna comprises a square cavity antenna or cross-source circular cavity antenna. 15
    [0008]
    The system of claim 6, wherein the well depth tool housing comprises one of a drill string tool housing or a drill string tool housing.
    [0009]
    A method, comprising: operating at least one transmitting antenna and a receiving antenna as equivalent dipole dipoles, wherein the inclined dipoles provide a selection of equivalent inclination angles for at least one of transmission antenna or receiving antenna; and receiving signals from the receiving antenna disposed in a geological formation, the signals being intended to be inverted to obtain at least one of the resistivity or dielectric constant properties of the geological formation at a selected depth of investigation the depth being determined by the selection of the equivalent tilt angles and the weighting with pre-calculated integrated radial sensitivity signal data.
    [0010]
    The method of claim 9, further comprising: recovering weight values corresponding to a desired level of integrated radial sensitivity and depth to be applied to the signals, producing weighted signal data.
    [0011]
    The method of claim 10, wherein the desired level of integrated radial sensitivity is a maximum value.
    [0012]
    The method of claim 9, further comprising: interpolating between weight values stored in a memory to derive weighting values corresponding to the selected investigation depth; and applying the weighting values on the signals, producing weighted signal data.
    [0013]
    The method of claim 10, further comprising: inverting the weighted signal data to determine at least one of the resistivity or dielectric constant properties of the geologic formation.
    [0014]
    The method of claim 9, further comprising: determining convergence of at least one of the resistivity or dielectric constant properties over a range of investigation depth, as a measure of model quality.
    [0015]
    The method of claim 9, further comprising: determining the divergence of the at least one of the resistivity or dielectric constant properties over a range of investigation depth, as a measure of existence formation transition zone. 5
    [0016]
    The method of claim 9, further comprising: selecting the depth of investigation by orienting at least one of the transmitting antenna or the receiving antenna to select one of the equivalent angles of inclination. 10
    [0017]
    The method of claim 9, further comprising: applying weight values corresponding to a desired level of integrated radial sensitivity and depth, to maintain the desired level of integrated sensitivity on more than one type of training. 15
    [0018]
    18. A method, comprising: simulating the operation of an inclined dipole antenna array in a simulated geological formation to obtain simulated signals over a predetermined range of equivalent magnetic dipole tilt angles and properties of the geological formation; determining the integrated radial sensitivity of the array with respect to the range of tilt angles of equivalent magnetic dipoles; determining weight values corresponding to the range of tilt angles of equivalent magnetic dipoles and to a desired depth of investigation; and storing the weight values in a memory, to allow the dynamic control of depth of investigation with respect to the measurement of resistivity or dielectric constant for a real geological formation when accessing the weight values and their application on actual signals received by one or more actual receiving antennas disposed in a real geological formation to generate weighted average values.
    [0019]
    The method of claim 18, further comprising: repeating the simulation, determining the integrated radial sensitivity of the array, and determining the weighted average values over a range of investigation depths.
    [0020]
    20. The method of claim 18, wherein determining the weighted average values comprises: selecting the weighted average values to provide a maximum value for the integrated radial sensitivity at the desired depth of investigation. 15 32
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    同族专利:
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    BR112017019282A2|2018-05-02|
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    US10429459B2|2019-10-01|
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    法律状态:
    2017-01-23| PLFP| Fee payment|Year of fee payment: 2 |
    优先权:
    申请号 | 申请日 | 专利标题
    PCT/US2015/026164|WO2016167771A1|2015-04-16|2015-04-16|Formation property measurement apparatus, methods, and systems|
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