• 专利附录
  • 专利说明
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    • 专利摘要:
    A depth positioning method for positioning a production logging tool (1) and a measurement log in a producing hydrocarbon well (3) obtained by means of the tool, the depth positioning method comprising: to generate (S1, S2, S3, S1 'S2', S3 ', S11, S12, S13) a set of magnetic measurements (MAG1, MAG) of a portion at depth of the hydrocarbon well from a first passive sensor along the deep portion of the hydrocarbon well, the magnetic measurement set comprising measurements of amplitude and / or direction of the magnetic field which forms a characteristic magnetic field pattern representative of a surrounding magnetic field the hydrocarbon well along the deep portion; comparing (S4, S4 ', S14) the set of magnetic measurements (MAG1, MAG) with another set of magnetic measurements (MAG_R, MAG2), the other set of magnetic measurements being a reference set of magnetic measurements generated either by an identical or similar passive magnetic sensor deployed and previously moved in the hydrocarbon well, either by a second passive magnetic sensor, separated from the first passive magnetic sensor by a given distance (DS), deployed and moved into the hydrocarbon well simultaneously ; and - determining (S4, S4 ', S14) the maximum correlation between the set of magnetic measurements (MAG1, MAG) and the reference set of magnetic measurements (MAG_R, MAG2), the maximum being related to the characteristic magnetic field pattern identifiable on part of the deep portion.
    公开号:FR3053382A1
    申请号:FR1756142
    申请日:2017-06-30
    公开日:2018-01-05
    发明作者:Eric Donzier；Linda ABBASSI；Emmanuel Tavernier
    申请人:OPENFIELD；
    IPC主号:
    专利说明:

    (57) A depth positioning method for positioning a production logging tool (1) and a measurement log in a hydrocarbon well (3) in production obtained by means of the tool, the positioning method in depth consisting of:
    - generate (S 1, S2, S3, S1 'S2', S3 ', S11, S12, S13) a set of magnetic measurements (MAG1, MAG) of a deep portion of the oil well from a first passive sensor along the depth portion of the oil well, the set of magnetic measurements comprising amplitude and / or direction measurements of the magnetic field which forms a characteristic magnetic field pattern representative of a surrounding magnetic field the oil well along the deep portion;
    - compare (S4, S4 ', S14) the set of magnetic measurements (MAG1, MAG) with another set of magnetic measurements (MAG_R, MAG2), the other set of magnetic measurements being a reference set of magnetic measurements generated either by an identical or similar passive magnetic sensor deployed and moved previously in the oil well, or by a second passive magnetic sensor, separated from the first passive magnetic sensor by a given distance (DS), deployed and moved in the oil well simultaneously; and
    - determine (S4, S4 ', S14) the maximum correlation between the set of magnetic measurements (MAG1, MAG) and the reference set of magnetic measurements (MAG_R, MAG2), the maximum being linked to the characteristic identifiable magnetic field pattern over part of the deep portion.
    l
    METHOD AND DEVICE FOR DEPTH POSITIONING A PRODUCTION LOGGING TOOL AND ASSOCIATED MEASUREMENT LOGGING OF A
    HYDROCARBON WELL.
    TECHNICAL FIELD The invention relates to a method for positioning a production logging tool and associated downhole measurements in the direction of the length of the well, with reference to a logging, in a hole drilling an oil well using passive magnetic measurements. The invention also relates to a deep positioning device and a production logging tool incorporating such a device. Such a device and such a tool generally operate in the severe downhole environment of hydrocarbon wells under pressure (generally in the range of 100 to 1500 bars) and temperature (generally in the range of 50 °) conditions. C at 200 ° C) downhole, and in corrosive fluid.
    STATE OF THE ART During drilling, evaluation, completion and then production of a hydrocarbon well, several parameters concerning the earth formations drilled and the various phases (eg oil, gas and water) multi-phase fluid mixtures flowing into the oil well borehole from the hydrocarbon containing areas are measured and monitored. Several measurement logs are carried out in order to evaluate and optimize the production of the oil well. For example, these measurements can relate to the flow contributions of the different perforated areas, to the identification of types and properties of fluids, such as the relative proportions (retention) of water, oil and gas, the presence of H 2 S, CO 2 , sand particles, limestone, asphaltenes, etc. Measurement logs can be used to decide on the implementation of corrective actions such as the closure of areas responsible for the unwanted production of water or sand.
    Production logging tools are generally deployed in the oil well borehole in order to carry out measurements and / or interventions. The production logging tools are lowered into the wellbore from the top of the oil well, the wellhead, to the bottom of the oil well. Production logging tools typically include multiple sensors for data acquisition such as pressure, temperature, fluid density, fluid speed, fluid conductivity along portions of the wellbore. Production logging tools are suspended by a line or cable that can also be used to communicate data in real time to surface equipment. Current oil wells often include a vertical well section, inclined well sections and horizontal well sections. In strongly inclined or horizontal wells, the weight of the tools not generating enough force to reach the bottom, coiled tubing, rods or tractors are used to push the tools along the wellbore. Production logging measurements are often made in sections of well casing with perforations.
    It is essential to know precisely the depth at which measurements are made by the sensors of the production logging tools. On the one hand, a hydrocarbon well can be several kilometers long and, on the other hand, the thickness of the areas of interest containing hydrocarbons may not exceed one meter. Commonly, the distance along the wellbore from the production logging tool to the surface is referred to as the depth, although this is not actually the true vertical depth given the inclination of the wellbore with respect to the vertical.
    There are several techniques for measuring depth.
    A first technique is based on the surface measurement of the length of cable or smooth cable deployed during the unwinding. Although the elongation produced by the effects of weight and thermal expansion can be corrected to some extent using modeling, errors in the field that can reach several tens of meters per kilometer are frequently observed in the field.
    Another technique is based on gamma ray measurements. A gamma ray sensor measures the natural radioactivity of rocks to provide a gamma ray signature of the geological layers traversed by the tool. The gamma ray signature is compared to reference logs from previous operations. One drawback is that the spatial resolution and the accuracy depend on the specific characteristics of the tank. Another disadvantage is that it is necessary to have reference gamma ray logs. In addition, the production of water with a high lime content can significantly affect gamma ray logging. In addition, the gamma ray sensor comprises a sodium iodide crystal coupled to a photomultiplier and to electronic boxes making it possible to generate high voltages and to count pulses. Thus, an additional disadvantage lies in the fact that the gamma ray sensor is bulky and expensive and therefore cannot be used for recording modules capable of being routed in the flow.
    There is also another technique of tubing joint locator tool (CCL) which includes strong permanent magnets generating magnetic flux outside the tool and coils detecting the variation in magnetic flux. The magnetic flux varies when the casing joint locator tool passes in front of the well junctions or casing joints whose wall is thicker at their threaded sections. A drawback is that the signal from the pipe joint locator (CCL) is difficult to repeat and depends on the speed of the tool, the current or voltage induced by the coil being directly linked to the variation of the magnetic flux associated with the movement of permanent magnets relative to the joint. As a result, when the Pipe Joint Locator (CCL) operates at low speed, its signal is very noisy and often difficult, if not impossible, to interpret. In addition, the spatial resolution is limited by the length of the casing sections of the well (typically 5 meters). Thus, a tubing joint locator tool allows the depth of the logs to be adjusted from different passes while being limited both over a short distance (generally less than one meter), and over a long distance (generally greater than 10 meters). An additional disadvantage is that a tubing joint locator will not work with production liners with flush joints or continuous liners such as coiled tubing. Furthermore, the tools for locating casing joints are also difficult to miniaturize given the fact that large permanent magnets are necessary to create sufficient magnetic flux and are expensive. The casing joint locator (CCL) tool is not compatible with integration into recording modules capable of being routed in the flow.
    Document US 7,260,479 describes a method of locating casing column joints using a measuring tool during drilling. The method includes deploying a measurement tool while drilling into a wellbore and measuring the magnetic field along a length of the wellbore. Changes in the magnetic field along the length of the wellbore are evaluated to determine the location of at least one tubing joint. According to this document, the method can be used, for example, during deflection operations to avoid milling a casing joint and can make it unnecessary to use a separate descent by wire rope in order to locate the casing joints. However, this method aims to locate particular characteristics on the geometry of the casing and does not offer the capacity for large-scale positioning, at the level of the size of the tank.
    Document WO 2011051429 describes a positioning tool making it possible to determine the position in a downhole casing. The positioning tool has a longitudinal tool axis and includes a detection unit comprising a first magnet for generating a magnetic field, a first sensor disposed in a first plane and at a first distance from the first magnet, for detecting changes in the magnetic field, and a second sensor disposed in the foreground and a second distance from the first sensor along the axis, also for detecting changes in the magnetic field.
    Document WO 2012082302 describes a method and apparatus for actuating a production logging tool in a wellbore and consists in acquiring a data set or a CCL logging from the wellbore which establishes a correlation between recorded magnetic signals and a measured depth, and selects a location within the wellbore to operate a wellbore device. The CCL log is then downloaded into a stand-alone tool. The tool is programmed to detect joints as a function of time, thereby providing a second CCL log. The autonomous tool also establishes a correspondence between detected joints and a physical signature from the first CCL log and then actuates the wellbore device at the selected location according to a correlation of the first and second logs. CCL.
    WO 2013007739 describes a positioning method for determining a position of a production logging tool moving at a certain speed in casing in a well, comprising the steps of measuring repeatedly over a period time an amplitude and / or a direction of a magnetic field by means of a first sensor when moving along a first part of the casing made of metal, determine a manufacturing pattern of the casing along the first part from the measurement, repeatedly measure over a period of time an amplitude and / or direction of a magnetic field using the first sensor when moving along a second part of the tubing made of metal, determine the speed of the tool along the second part, adjust the speed of the tool thus determined along the second part on the basis of the manufacturing pattern.
    Document WO 2013092836 describes a downhole mapping system making it possible to identify completion components having an internal surface in a casing in a completion. The downhole mapping system includes a magnetic pickup tool having a longitudinal tool axis and including a detection unit. The detection unit includes a first magnet for generating a magnetic field, and a first sensor disposed in a first plane and at a first distance from the first magnet, for detecting changes in the magnetic field. The sensor detects changes in the magnitude and / or direction of the magnetic field producing measured data from a casing profile. The downhole mapping system further includes a reference database including magnetic reference data of the completion components, and a processor comparing a set of the measured data with reference data from the database to identify a substantially corresponding set of data representing a completion component stored in the reference database. The system further includes a component scanning unit for scanning the internal surface to identify a component and store data representing the component in the database.
    Document WO 2015009373 describes an apparatus and method for locating a joint of a casing placed in a borehole. The device includes a sensor oriented in a plane perpendicular to a longitudinal axis of the casing. The sensor measures a magnetic field induced in the casing by the earth's magnetic field. A tool transports the sensor through the tubing along a path that is radially offset from a longitudinal axis of the tubing. Cross-sectional measurements of the magnetic field are obtained by the sensor at a plurality of depths along the casing. A modification of the transverse measurements is identified and used to determine the location of the casing joint.
    Since it is essential to have a precise and reliable depth, most operations must use several of the techniques described above and depth logs require rigorous analysis when interpreting log data. .
    SUMMARY OF THE INVENTION The purpose of the invention is to provide a method of deep positioning for positioning a production logging tool and a measurement logging obtained by means of said tool in a borehole d '' a hydrocarbon well in production using magnetic measurements which overcome one or more of the limits specific to existing processes and / or devices.
    The deep positioning method according to the invention is based on the deployment of one or more magnetic field sensors of high sensitivity integrated (s) in a production logging tool in order to detect particular / specific patterns of the natural magnetic field present inside the wellbore which can be linked to a particular / specific position along the wellbore. The magnetic field inside the wellbore is related to the distortion of the earth's magnetic field due, for example, to the geometry and properties of the metal materials of the well casing as well as to the influence of the properties of the rocks. In practice, this leads to a complex and unique distribution of the magnetic field along the wellbore. The measurement of such anomalies in the Earth's magnetic field along the wellbore provides signatures with very high spatial resolution, generally having characteristics of less than one meter, as well as long-range patterns, the signatures of which are recognizable over several tens or even several. hundreds, of meters. Comparisons of magnetic logs between different passes and tool campaigns allow the depth positions of all measurement logs in the wellbore to be associated or aligned. In particular, the method can be applied to precisely position the production logging tool with respect to a previous operation where magnetic logging is used as a reference. The embodiments of the method used to control the depth are based on the correlation between the magnetic field logs with reference to the logs obtained during previous campaigns or passes, compared with the prior art methods based on the CCL. , natural magnetic field logs provide depth correlation with unprecedented repeatability. Advantageously, this method can be applied to small devices such as recording modules capable of being routed in the flow.
    An embodiment of the method makes it possible to locate the production logging tool with precision with respect to a reference magnetic field logging. This embodiment does not directly provide absolute precision on the depth. In fact, any error in depth from the reference log is passed on to the following tool campaigns. However, while absolute precision is not essential for many operations, repeatability is essential, for example to align measurements with high and low positions of each perforated area of interest.
    Another embodiment of the method uses the correlation of magnetic signatures between two or more magnetic field sensors separated by a known distance. This embodiment makes it possible to deduce a precise tool depth from the calculation of the flight time and the integration of time.
    In one aspect, there is provided a depth positioning method for positioning a production logging tool and a measurement logging in a hydrocarbon well in production obtained by means of said tool, the depth positioning method consisting at :
    generating a set of magnetic measurements of a depth portion of the oil well from a first passive sensor along the depth portion of the oil well, the set of magnetic measurements comprising amplitude measurements and / or direction of the magnetic field which forms a characteristic magnetic field pattern representative of a magnetic field surrounding the oil well along the deep portion;
    - compare said set of magnetic measurements with another set of magnetic measurements, the other set of magnetic measurements being a reference set of magnetic measurements generated either by an identical or similar passive magnetic sensor deployed and moved previously in the oil well or by a second passive magnetic sensor, separated from the first passive magnetic sensor by a given distance, deployed and moved in the oil well simultaneously;
    determining the maximum correlation between the set of magnetic measurements and the reference set of magnetic measurements, said maximum being linked to the characteristic magnetic field pattern identifiable on a part of the depth portion.
    When the reference set of magnetic measurements is generated by the identical or similar passive magnetic sensor deployed and previously moved in the hydrocarbon well, the method can also consist of:
    determining a depth offset between the two sets of magnetic measurements by determining the maximum of correlation in a sliding depth window;
    calculating a corrected depth log; and correcting a depth positioning scale of a log of measurements taken by another sensor sensitive to at least one property of a multiphase flow mixture flowing in the oil well or to at least one property of a formation surrounding the oil well based on the corrected depth log and a position of said sensor relative to the first passive magnetic sensor.
    The step of determining a depth offset can include:
    - a first optimization loop scanning depth offset values and determining the depth offset which corresponds to a maximum of correlation; and
    - a second optimization loop scanning depth window values between a depth window of several tens of meters and a depth window of a few meters.
    When the reference set of magnetic measurements is generated by the second passive magnetic sensor separated from the first passive magnetic sensor by the given distance deployed and moved in the hydrocarbon well simultaneously, the method can also consist of:
    determining a time of flight between the two sets of magnetic measurements by determining the maximum of correlation in a sliding time window;
    îo - calculate a speed of the first passive magnetic sensor along the deep portion of the oil well;
    calculating a depth log based on said speed and an initial reference position; and generating a reference magnetic log by correcting a depth positioning scale of the first set of magnetic measurements based on said depth log.
    The step of determining a flight time may include:
    - a first optimization loop scanning time of flight values and determining the time of flight which corresponds to a maximum of correlation; and
    - a second optimization loop scanning time window values between a time window of several tens of seconds and a time window of a few seconds.
    The deep positioning method can also consist of:
    generating a first set of positioning measurements associated with the magnetic measurement set of the first passive magnetic sensor, and a second set of positioning measurements associated with the magnetic measurement set of the second passive magnetic sensor, the two sets of positioning measurements being generated by a first positioning sensor and a second positioning sensor in proximity to the first passive magnetic sensor and the second passive magnetic sensor that are deployed and moved in the oil well simultaneously, respectively;
    calculate magnetic measurements in a cylindrical or spherical coordinate system; and generate a reference magnetic log as a function of the radial distance p, the azimuth φ and the height z along the cylindrical coordinate subject, or the radius r, the elevation and the azim ut φ according to the syene of spherical coordinates.
    The depth positioning method according to the invention can make it possible to determine a speed of a production logging tool deployed and moved along the depth portion of the oil well, the production logging tool comprising at least two passive magnetic sensors.
    The depth positioning method according to the invention can make it possible to determine a density of the wellbore fluid flowing in the depth section of the borehole of the oil well by correcting the positioning scale by depth of a pressure gradient measurement log obtained from a pressure sensor and calculating the density by dividing the pressure gradient by Earth's gravity, possibly corrected by the cosine of the inclination of a oil well in case of an inclined oil well.
    The deep positioning method according to the invention can make it possible to evaluate the integrity of the hydrocarbon well by comparing the reference clearance of the magnetic measurements taken previously corresponding to an undamaged well casing, to a subsequent clearance magnetic measurements indicating magnetic anomalies corresponding to damaged well casing and by connecting said anomalies to depths comprising portions of damaged well casing.
    In another aspect, there is provided a depth positioning device for positioning a production logging tool and a measurement logging in a hydrocarbon well in production obtained by means of said tool, the depth positioning device including:
    a first passive magnetic sensor designed to generate a set of magnetic measurements of a depth portion of the oil well, the set of magnetic measurements comprising multiple measurements of amplitude and / or direction of the magnetic field which forms a pattern of characteristic magnetic field ll representative of a magnetic environment of the borehole along the depth portion;
    means for deploying and moving the first passive magnetic sensor through the borehole along the deep portion of the oil well;
    a processing unit:
    • designed to compare said set of magnetic measurements with another set of magnetic measurements, the other set of magnetic measurements being a reference set of magnetic measurements generated either by an identical passive magnetic sensor îo or similar deployed and previously moved in the well of hydrocarbons, either by a second passive magnetic sensor, separated from the first passive magnetic sensor by a given distance, so as to be deployed and moved in the oil well simultaneously, and • designed to determine the maximum correlation between the play of magnetic measurements and the reference set of magnetic measurements, said maximum being linked to the characteristic magnetic field pattern identifiable on a part of the depth portion.
    The depth positioning device may further comprise a first positioning sensor near the first passive magnetic sensor and a second positioning sensor near the second passive magnetic sensor.
    The depth positioning device may further comprise at least one electronic card comprising a quartz oscillator, a memory chip, the passive magnetic sensor produced in the form of a three-axis magnetometer chip, a positioning sensor produced under the form of a three-axis accelerometer chip, the whole being connected to the processing unit produced in the form of a microcontroller.
    The deep positioning device may further include two electronic cards positioned at the given distance from one another.
    According to yet another aspect, there is provided a production logging tool comprising a depth positioning device according to the invention and at least one sensor sensitive to at least one property of a mixture of multiphasic flow s' flowing into the oil well or at least one property of a formation surrounding the oil well borehole.
    According to yet another aspect, a recording ball is provided comprising a protective envelope of spherical shape having an average density allowing it to be driven along the hydrocarbon well by a mixture of multiphase flow flowing in the oil well, a battery, an electronic card connected to at least one sensor sensitive to at least one property of the multiphasic flow mixture or to at least one property of a formation surrounding the oil well and to a device for deep positioning according to the invention.
    With the method and device according to the invention, it may be possible:
    • to improve the determination of the position of production logging tools and their associated measurements in a well, generally making it possible to obtain a resolution of less than a meter and a far-reaching precision whose signatures are recognizable over several tens, or even several hundred, meters;
    • improve the repeatability over time of depth measurements;
    • improve depth accuracy during well operations;
    • to provide a methodology for merging measurement logs obtained during different campaigns and production log tool passes;
    • to provide a new methodology for interpreting depth logs;
    • accurately position production logging tools in the oil well;
    • deduce new measurements from precise depths to better understand the conditions of the oil wells (for example, determining the density of fluid);
    • allow deployment in open hole sections of oil wells in production;
    • to allow integration into recording modules capable of being moved in the flow (recording ball); and • achieve low cost and easy maintenance thanks to the simple, robust and compact structure of the tool.
    Other advantages will appear on reading the following description of the invention.
    SUMMARY DESCRIPTION OF THE DRAWINGS The present invention is illustrated by means of examples and is not limited to the appended drawings, in which identical references indicate similar elements:
    • Figure 1 is a cross-sectional view schematically illustrating a production logging tool comprising a deep positioning device deployed in a wellbore of a hydrocarbon well in production;
    • Figure 2 is a perspective view of a production logging tool including a deep positioning device;
    · Figure 3 is a perspective and transparent view showing the deep positioning device in the production logging tool of Figure 2;
    • Figure 4 is an enlarged perspective view of the electronic card of the deep positioning device of Figure 3;
    · Figure 5 is an exploded perspective view showing the device for deep positioning in a recording module capable of being conveyed in the flow or recording ball;
    • Figures 6 to 8 schematically illustrate several embodiments of the deep positioning method;
    · Figures 9 to 13 are diagrams illustrating typical magnetic signatures measured using the deep positioning device according to the invention and used to implement at least one embodiment of the deep positioning method according to the invention.
    DETAILED DESCRIPTION [00043] The invention will be understood on reading the description which follows, made with reference to the accompanying drawings.
    Figure 1 is a cross-sectional view schematically illustrating a production logging tool 1 comprising a depth positioning device 11 deployed in a wellbore 2 of an oil well 3 which has been drilled in a land formation 4. The borehole means the drilled hole or borehole, comprising the open hole or uncased portion of the well. The borehole designates the inside diameter of the wall of the borehole, the rock wall which delimits the borehole. The open hole designates the uncased part of a well. Although most completions are cased, some are open, particularly in horizontal or extended span wells where it is sometimes impossible to effectively cement the casing. The deep positioning device 11 is capable of performing any embodiment of the deep positioning method according to the invention in a hydrocarbon well in the production phase. For example, this depth positioning device 11 can be incorporated into the production logging tool 1. The production logging tool 1 can comprise several subsections 5 offering different functions, a centralizer 6, and be coupled to surface equipment by a metal cable 7. At least one sub-section comprises a measuring device generating measurement logs, that is to say measurements as a function of depth or time, or both, of one or more of the physical quantities in or around a well. Wire rope logs are taken downhole and then transmitted by wire rope to the surface where they are recorded. Surface equipment is well known in the petroleum industry, and is therefore not illustrated or described in detail in this document. Numerous logging measurements (e.g. electrical properties, including resistivity and conductivity at various frequencies, acoustic properties, active and passive nuclear measurements, dimensional wellbore measurements, formation fluid sampling, pressure measurement a formation ...) are possible with such a production logging tool 1 during its movement along and inside the hydrocarbon well 3 drilled in the underground formation 4. The wellbore 2 comprises a cased portion 8. The cased portion 8 may include a corroded area 9 (damaged well casing section) and a perforated area 10.
    Various inputs of fluid F1, F2 (which may include solid particles) can occur from the underground formation 4 towards the borehole 2.
    Figure 2 is a perspective view of the production logging tool
    I comprising a deep positioning device 11. The production logging tool 1 comprises an upper section 21, a centralizer 22 and a lower part 23. The lower and upper parts 21, 23 comprise suitable connection means 24 (a alone being represented in Figure 2) to other sections of the tool, and / or to other tools (tool train) and / or to traction means and / or to a line allowing communication with surface equipment. The production logging tool 1 typically comprises several sensors 5 arranged inside the tool housing and / or along the tool housing and / or connected to the arms of the centralizer. These sensors measure various parameters of the fluid F1, F2 inside the wellbore 2 and / or flowing from the underground formation 4 around the wellbore 2 as is usual in the art (for example pressure, temperature, density of the fluid, speed of the fluid, conductivity of the fluid ...).
    Several sensors can be installed at the top, the middle or the bottom of the production logging tool in order to allow a measurement of the speed of the tool from a time of flight measurement of anomalies of the magnetic field.
    Figure 3 is an exploded, transparent perspective view illustrating an exemplary embodiment of the deep positioning device 11 in the production logging tool 1 of Figure 2. The lower section 23 includes a frame mounting 25 for supporting and mounting the electronic card 26 of the deep positioning device 11. The electronic card 26 is circular. Other electronic cards associated with other sensors or devices of the production logging tool can be mounted at a certain distance above and / or below the electronic card
    26 of the depth positioning device 11.
    Figure 4 is an enlarged perspective view of an exemplary embodiment of the electronic card 26 of the depth positioning device
    II of FIG. 3. The electronic card 26 comprises several holes 27 making it possible to fix the card to the mounting frame 25 and to route appropriate wire connectors (for example power and data / not shown). In a first embodiment, the electronic card 26 comprises a passive magnetic sensor 28, a processing unit 29, a memory 30 and a quartz oscillator 31. The passive magnetic sensor 28 can be an integrated circuit with a MEMS magnetometer, a magnetometer to either one, two or three axes. The processing unit 29 can be a microcontroller. In another embodiment, the electronic card 26 may further comprise an accelerometer and / or a gyroscope, for example an integrated circuit with a 3-axis MEMS accelerometer-gyroscope 32 (that is to say grouping both the functions of the 3-axis gyroscope and the 3-axis accelerometer).
    Another depth positioning device 11 comprising a second passive magnetic sensor can be fixed in the upper part 21 of the production logging tool 1 in the same manner as the first passive magnetic sensor 28 in the lower section 23. In this case, the two passive magnetic sensors are separated from each other by a fixed and given distance DS, for example a meter in the production logging tool of FIG. 2.
    The housing of the production logging tool 1 is suitably manufactured in a non-magnetic material such as stainless steel (for example stainless steel sold under the brand Inconel) in order to minimize the effect of housing / tool mechanics on passive magnetic sensor measurements. The centralizer 22 allows good centering of the tool so that the sensor is always positioned in the same place in the wellbore between successive passes and in order to measure stable anomalies in the earth's magnetic field. Alternatively, however, an acceptable measurement can also be obtained with a production logging tool that is not equipped with a centralizer.
    Figure 5 is an exploded perspective view showing the device for deep positioning in a recording module capable of being moved in the flow or recording ball 40. The recording ball 40 is an autonomous measuring device which can be released at the bottom of the hole in the wellbore to be brought to the surface by the fluids and collected at the surface (i.e. at the head of the well). The launch of the recording ball can be programmed in advance at specific times or according to events detected at the bottom of the hole. As it rises to the surface, the recording ball performs various measurements. The recording ball has a sufficiently low average density, for example less than 1.8 g / cm 3 , preventing it from remaining at the bottom of the hole and allowing it to be drawn along the well with the flow. Such record balls can provide downhole data at critical moments in the operation of the oil well and in places where electrical or optical communications cables cannot be laid. For example, such recording balls make it possible to control multizone hydraulic fracturing operations in horizontal and multilateral wells. A recording ball 40 includes a protective covering 41 which may be in the form of a hollow sphere made of a material such as titanium, in order to provide sufficient resistance to pressure while minimizing the thickness of the wall. Such a sphere can have a diameter of between 2 cm and 5 cm. The recording ball 40 comprises inside the envelope 41 a battery and a battery support 42, an electronic card 43 and an electronic card support 45 comprising the depth positioning device 11 according to the invention, an electronic processor and a memory. Various sensors 44 (for example a pressure sensor, a temperature sensor, etc.) connected to the electronic card 43 can be coupled outside of the envelope 41. The envelope 41 can consist of two hemispheres which are securely coupled together in leaktight manner by fastening means 46 and suitable seals 47. The inertial sensors, gyroscopes, accelerometers and magnetometers of the positioning device 11 make it possible to calculate the speed and the trajectory of the recording ball during its ascent to the surface. This information can provide guidance regarding fluid entry along the well, in particular by measuring the acceleration of the module with flow.
    Figures 6 to 8 schematically illustrate several embodiments of the deep positioning method.
    Figure 6 schematically illustrates a first embodiment of the deep positioning method. This embodiment requires the use of two passive magnetic sensors, the first and second passive magnetic sensors being triaxial magnetometers generating three-dimensional signals separated by a given distance DS. The data acquisition sequencing scan period (the inverse of the SR scan frequency) is a function of the time interval between two measurements made at a time t, and tj + 1, ie tj +1 -ti = SP = 1 / SR, for example SP is 0.1 seconds. This is precisely controlled by the processing unit 29 connected to the crystal oscillator 31. In a first step S1, the first magnetic sensor provides first signals MAG1x (ti), MAG1y (ti), MAG1z (t,) corresponding to the magnetic field in three dimensions at a first position X1 and the second magnetic sensor provides second signals MAG2x (tj), MAG2y (ti), MAG2z (tj) corresponding to the magnetic field in three dimensions at a second position X2. In a second step S2, the first signals and the second signals are filtered (for example to attenuate the noise of the signals) and the module is calculated (square root of îo MAG1x (tj) 2 + MAG1y (ti) 2 + MAG1z (ti ) 2 and, respectively, square root of MAG2x (ti) 2 + MAG2y (tj) 2 + MAG2z (tj) 2 ). In a third step S3, the first and second filtered signals MAG1_F (tj) and MAG2_F (tj) are buffered in memory 30. The whole of the measurement procedure or a portion of time of a measurement procedure can be stored in memory. Thus, after a given time interval, the memory contains two sets of magnetic measurements associated with the first and second magnetic sensors. In a fourth step S4, characteristics or patterns in the magnetic field measured by the first magnetic sensor at a time t, are recognized by comparison with the magnetic field measured by the second sensor at a later time t, + t fJ . The calculation of pattern recognition and of the time delay or flight time TF (i) is carried out by defining a sliding time window TW k on the magnetic measurement data and by calculating a correlation value. A first optimization loop (n ° 1) generates time of flight increment values t ^ and the processing unit calculates the following summary formula and determines the time of flight value TF (i) which corresponds to a maximum of the sum indicating the best possible correlation (i.e. the time delay which maximizes the correlation value):
    The flight time values of the first optimization loop are included in a time window covering the flight time estimated from the speed of the wire rope plus and minus a certain percentage, generally 20%. The maximum value is obtained for an optimal match between the signature curves in the time window TW k chosen. The time window should be large enough to include identifiable patterns and short enough to correspond to a constant tool speed. Although dependent on the characteristics of the well, the log and the tool, the time window TW k is generally chosen in an interval of a few seconds to a few tens of seconds. An efficient way to determine the optimal TW time window is using a second optimization loop (# 2). The time window TW k is decremented in stages starting from a time window TW 0 of several tens of seconds and reducing it to a time window TWf of a few seconds. Alternatively, incrementation from a time window TWf of a few seconds to a time window TW 0 of several tens of seconds is also possible. The optimal TW time window is given for the maximum correlation value calculated above.
    In this way, in a fifth step S5, the time of flight value TF (i) makes it possible to calculate the speed V (tj) of the production logging tool along the wellbore, that is:
    V (tj) = (X2-X1) / TF (i) = DS / TF (i)
    Then, by an integration calculation, it is possible to calculate the distance traveled by the production logging tool. In a sixth step S6, a depth log (DEPTH LOG) is calculated on the basis of said tool speed V (tj) and an initial reference position DEPTH 0 , that is:
    The reference position DEPTHO can be either zero, that is to say the depth at the surface or wellhead, or an arbitrary position close to an area of interest (for example the position of a completion element such as a change in column diameter). In a seventh step S7, a magnetic reference log MAG_R (DEPTH (ti)) is generated and will be used to precisely position the tools and correct the measurement logs from other passes and other campaigns.
    [00054] Thus, the correlation of magnetic field logging can make it possible to obtain better depth accuracy (and not only repeatability).
    'In order to achieve this, rather than measuring the magnetic field at a single location in the tool, at least two measurements are made, separated by a known distance. With two or more sensors distributed along the length of the production logging tool, the recognition of magnetic signatures with a time delay between two sensors makes it possible to calculate a reliable tool speed using the time of flight determination technique . This speed measurement is unaffected by wire rope length errors and provides the basis for accurate reference magnetic logging. The only requirement is to define a reference starting point, preferably the reference depth point chosen just above the production area where the data is most important. In addition, a location with a particular signature of a remarkable magnetic field pattern is advantageous for facilitating identification during future operations. The depth below this reference depth is calculated by taking the integral of the velocity with respect to time. All future magnetic field logs will be correlated to this log.
    Having a precise depth makes it possible to deduce new measurements and better understand the well conditions. For example, from a simple pressure measurement, it is possible to extract the density of the fluid present inside the wellbore, provided that this depth is known very precisely. Indeed, the pressure gradient, that is to say the pressure variation compared to the depth, is a direct measure of the density multiplied by the earth's gravity for a vertical wellbore. For an inclined wellbore, the result is corrected by the tilt cosine. State of the art depth measurements give poor results, and operators often use nuclear tools based on gamma attenuation to measure fluid density. With the depth logs obtained using the method according to the invention, the precision obtained on the fluid density rivals nuclear technology without additional cost on operations and without risk to the environment. In addition, knowing the speed of the tool makes it possible to calibrate flow sensors which measure the speed of the fluid relative to the tool and not relative to the wellbore.
    Figure 7 schematically illustrates another embodiment of the depth positioning method. This embodiment differs from the first embodiment in that the first and second passive magnetic sensors are triaxial magnetometers coupled to triaxial accelerometer-gyroscope sensors generating magnetic and acceleration signals in three dimensions, respectively. Thus, in the first step S1 ′, the first magnetic sensor supplies first signals MAG1x (ti), MAG1y (ti), MAG1z (tj) corresponding to the magnetic field in the three dimensions. Furthermore, the second magnetic sensor provides second signals MAG2x (ti), MAG2y (tj), MAG2z (tj) corresponding to the magnetic field in the three dimensions. The accelerometer sensor provides the first signals ACCIx (tj), ACC1y (tj), ACC1z (ti) corresponding to the acceleration in the three dimensions. A gyroscope can be added or integrated into the accelerometer to calculate a reliable and precise acceleration vector even when the tool is moving or vibrating. In the second step S2 ′, the first signals and the second signals are filtered and the values of the module IMAG1 l (tj), IMAG2l (ti), of the elevation MAG10 (ti), MAG20 (tj) and the azimuth MAG1 (p (ti), MAG2ç (ti) of the magnetic field according to a spherical coordinate system are calculated, and the inclination 0 (ti) and the azimuth <p (ti) of the tool can be determined at from the measurements of the accelerometer-gyroscope. Thereafter, the steps are identical to those of the first embodiment with the difference that three magnetic reference logs of module IMAG_RI (DEPTH (tj)), of elevation MAG6_R ( DEPTH (ti)) and azimuth MAG <p_R (DEPTH (tj)) can be generated by correcting a depth positioning scale from one of the magnetic measurement sets based on the DEPTH (tj) depth log in the spherical coordinate system (step S7 '). Alternatively, in a similar way, the correlation analysis can also be performed on the 3 axes of the vec magnetic field or at any angle to the axis of the wellbore. Correlation on the direction of the vector (e.g. elevation, azimuth) provides further details regarding magnetic signatures and improves the ability to detect anisotropic anomalies. This is advantageous when logging through completion equipment that has shapes that are not symmetrical about the axis such as side pocket chucks or a measurement tube or casing damage to sections of deviated wellbore where corrosion is frequently observed due to stagnation of water in the lower part of the tube or casing.
    Figure 8 schematically illustrates yet another embodiment of the deep positioning method. This embodiment requires the use of a single passive magnetic sensor, and the previous generation of a first set of magnetic measurements (step S0) to produce a magnetic reference log MAG_R (DEPTH). As in the other embodiment, the scanning frequency of the data acquisition sequencing SR is a function of the time interval between two measurements carried out at a time t, and t i + 1 , ie t i + itj = SP = 1 / SR, for example SP is 0.1 seconds. In a first step S11, the magnetic sensor supplies a signal MAG (tj) corresponding to the magnetic field module at a reference location for the tool train, that is to say the location of the magnetic sensor. In a second step S12, the signal MAG (tj) is filtered. In a third step S13, the filtered signals MAG_F (tj) are buffered in the memory 30. After a given time interval, the memory contains a second set of magnetic measurements associated with the estimated depth DEPTH W (ti), by example, using the wire rope depth measurement system (see details in the history section). It should be noted that the wire rope depth measurement system can provide measurements either in real time (simultaneously or almost simultaneously with the passive magnetic sensor), or offline if used as a recorder (acquisition the depth measurement system by wire rope and the passive magnetic sensor results from two different acquisition systems). This second set of magnetic measurements constitutes an uncorrected magnetic log MAG_F (DEPTH_W). In a fourth step S14, the characteristics or patterns in the magnetic field measured by the magnetic sensor at the depth DEPTH_W are recognized by comparison with the magnetic field of the reference magnetic logging MAG_R (DEPTH). The calculation of pattern recognition and DEPTH_SHIFT depth offset (j) is performed by defining a sliding depth window DW k on the magnetic measurement data and by calculating a correlation value. A first optimization loop (n ° 1) generates incremental offset values DEPTH_SHIFT (j) and the processing unit calculates the following summary formula and determines the depth offset • DEPTHSHIFT which corresponds to a maximum of the sum indicating the best possible correlation (i.e. the depth offset value that maximizes the correlation value) inside the corresponding DW k depth window:
    Such a correlation calculation is performed by taking the product of the offset and non-offset curves on a window DW k . The maximum value is obtained for an optimal match between the signature curves in the depth window îo DW k chosen. The depth window should include identifiable patterns that can be associated with a section of the well with a high confidence level, i.e. with a very low probability that another section of the well may have a pattern or a identical signature. In practice, the optimal DW depth window is the largest possible which includes unique well patterns, up to several tens of meters long, but small enough that the depth correction remains constant in this depth window (which depends accuracy of the wire rope depth). This method allows to obtain a high level of confidence on the position as well as a high spatial resolution on corrected logs. An effective way to determine the optimal DW depth window is using a second optimization loop (# 2). The window of depth DW k is decremented in stages starting from a window of depth DW 0 of several tens of meters and reducing to a window of depth DW f of a few meters. Alternatively, incrementation from a window of depth DW f of a few meters to a window of depth DW 0 of several tens of meters is also possible. The optimal DW depth window is given for the maximum correlation value calculated above.
    In this way, in a fifth step S15, the depth offset value
    DEPTH_SHIFT (i) calculates a corrected depth log
    DEPTH C (i), either:
    DEPTH_C (i) = DEPTH_W (i) + DEPTH_SHIFT (i)
    In a sixth step S16, a corrected magnetic log MAG_F (DEPTH_C) is calculated on the basis of said corrected depth log DEPTH_C (i). In a seventh step S17, all the measurement logs taken by other sensors of the production logging tool can be corrected according to the depth positioning by performing a new calculation using the corrected depth log DEPTH_C (i) on the basis of the position of the sensor concerned relative to the passive magnetic sensor (distance X between the first passive magnetic sensor and the other sensor).
    îo [00058] In the case of a production logging tool operating in recorder mode, the “wire rope depth” and the “magnetic depth” are obtained from two separate acquisition systems which generate two data files as a function of time. These data files are merged with each other after retrieving the production logging tool from the surface and after downloading the tool's memory. The file merging step generates a file with magnetic measurements which are synchronized as a function of the depths of the wire rope (during the third step S13), all the following steps in Figure 8 being identical.
    Figures 9 to 13 are diagrams illustrating typical magnetic signatures measured using the depth positioning device according to the invention and used to implement at least one embodiment of the depth positioning method according to the invention.
    Figure 9 shows an example of the MAG magnetic measurement logs (solid line) in a gas well compared to CCL measurements (dotted line) and gamma ray GR measurements (broken line) for a depth interval from 5,259 m to 5,319 m. The CCL measurements have significant peaks corresponding to the locations of the joints, only these significant peaks are repeatable while unstable signals can be observed between them. Gamma ray measurements are difficult to interpret in a depth interval as short as about 60 m. Unlike CCL and gamma ray measurements, the magnetic measurement log according to the invention contains high resolution characteristics / patterns which are repeatable and identifiable both on a large scale over hundreds of meters and at a resolution below a meter. Magnetic logging provides a unique signature of the entire well as well as its portions, the magnetic logging representing the footprint of the well. The wide range of length scales of information-rich patterns (patterns with a very low probability of being reproduced elsewhere in the same well or in another well) makes it possible to determine precisely and reliably the position at which these patterns match. This remarkable characteristic is due to the fact that the magnetic field in the wellbore is influenced by several phenomena which also have a large range of length scales such as the earth's magnetic field itself with its anomalies, the presence of layers magnetized rock, proximity to completion tubes (casing, tube, joints, mandrels, sieve ...), geometries and properties of materials ...
    Figure 10 shows two passes (rising and falling) in a gas well of a production logging tool comprising a CCL device and a magnetic sensor of a depth positioning device, that is to say say magnetic MAG measurements (high signals MAG_PASS_DWN1 and MAG_PASS_UP1) compared to CCL measurements (low signals CCL_PASS_DWN1 and CCL_PASS_UP1). The rising and falling passes MAG_PASS_DWN1 and MAG_PASS_UP1 demonstrate that the magnetic signature is repeatable since the two signals resulting from the rising and falling passes overlap relatively well.
    Figure 11 shows two passes (up and down) of a production logging tool comprising a magnetic sensor of a depth positioning device, the measurements of the two passes being taken at a different speed, in this example respectively 10 and 20 meters per minute (solid line MAG_PASS_DWN1 and dotted line MAG_PASS_UP2). Note that in the initial acquisition, the magnetic signatures of the two passes do not match. An analysis shows that this is due to a reference depth provided by the wire rope system having an error of several meters. Figure 12 shows that by applying a correction of 4.5 m on the wire rope reference values, one obtains an almost perfect agreement in the depth interval between 5300 m and 5310 m (between the two signals MAG_PASS_DWN1 in line full and MAG_PASS_UP2_DEPTH CORRECTED in dotted lines). The correction is obtained using the embodiment described above in relation to Figure '8. More generally, pattern recognition algorithms can be used to perform continuous correction of depth logging by defining a window sliding DW depth (an example of DW depth window is indicated by a broken line rectangle in Figure 12) on the magnetic signature and determining the depth offset which maximizes the correlation. The correlation method makes it possible to define a precise depth reference for the logs which cannot be carried out solely using the conventional gamma ray and CCL methods. Thus, the interpretation of measurement logs made by other sensors (pressure, temperature, density, conductivity ...) and the planning of corrective actions are greatly improved.
    Figure 13 shows the signals MAG_SENSOR1 and MAG_SENSOR2 from two passive magnetic sensors at a distance of one meter from each other. By shifting the signal of the second MAG SENSOR2 DELAYED sensor over time after having implemented the deep positioning method according to the first embodiment of the deep positioning method (see Figure 5) and determined the flight time TF ( i), it is observed that the patterns
    MAG SENSOR1 and MAG_SENSOR2_DELAYED correspond [00064] It should be understood that embodiments of the production logging tool according to the present invention are not limited to the embodiment representing a vertical oil well drilling, the invention being also applicable regardless of the configuration of the wellbore, in particular horizontal, deviated or a combination of vertical, deviated and / or horizontal portions, with or without casing. Furthermore, the magnetic depth positioning device according to the invention is not limited to an application to a production logging tool, but can be easily adapted to multiple applications in analysis tools operating under pressure conditions. and downhole temperature, such as a cable work tool, a tool connected to a tractor, off-center tools that deploy gas extraction valves or gauges inside side pocket chucks, shutters, cutting tools ... For complex well completion configurations with valves, gas extraction chucks, pumps, chemical injectors, sand screens ... where the deployment of lines, of cables, rods or casing is difficult or even impossible, magnetic measurements can be carried out by autonomous miniature recording modules which circulate through the well and are routed in the ec only to the surface and then retrieved to download the recorded magnetic measurements, simultaneously with other fluid or training related measurements. All of these tools would greatly benefit from the integration of the device and method of in-depth positioning according to the invention in order to help locate the precise position of the intervention.
    权利要求:
    Claims (15)
    [1" id="c-fr-0001]
    1. A deep positioning method for positioning a production logging tool (1) and a measurement log in a hydrocarbon well (3) in production obtained by means of said tool, the deep positioning method consisting in :
    - generate (S1, S2, S3, ST, S2 ', S3', S11, S12, S13) a set of magnetic measurements (MAG1, MAG) of a deep portion of the oil well from a first passive sensor along the depth portion of the oil well, the magnetic measurement set comprising amplitude and / or direction measurements of the magnetic field which forms a characteristic magnetic field pattern representative of a surrounding magnetic field of the oil wells along the deep portion;
    - compare (S4, S4 ', S14) said set of magnetic measurements (MAG1, MAG) with another set of magnetic measurements (MAG_R, MAG2), the other set of magnetic measurements being a reference set of magnetic measurements generated either by an identical or similar passive magnetic sensor deployed and moved previously in the oil well, or by a second passive magnetic sensor, separated from the first passive magnetic sensor by a given distance (DS), deployed and moved in the oil well simultaneously ; and
    - determine (S4, S4 ', S14) the maximum correlation between the set of magnetic measurements (MAG1, MAG) and the reference set of magnetic measurements (MAG_R, MAG2), said maximum being linked to the characteristic identifiable magnetic field pattern over part of the deep portion.
    [2" id="c-fr-0002]
    2. The deep positioning method according to claim 1, when the reference set of magnetic measurements (MAG_R) is generated by the identical or similar passive magnetic sensor deployed and moved previously in the oil well (3), consisting of in addition to:
    - determining (S14) a depth offset (DEPTHSHIFT) between the two sets of magnetic measurements (MAG, MAG_R, MAG_F) by determining the maximum correlation in a sliding depth window (DW k );
    - calculate (S16) a corrected depth log (DEPTH_C); and
    - correct (S17) a depth positioning scale of a log of measurements taken by another sensor sensitive to at least one property of a multiphase flow mixture (F1, F2) flowing in the oil well (3) or at least one property of a formation (4) surrounding the oil well (3) on the basis of the corrected depth log (DEPTHC) and of a position (X) of said sensor relative to the first passive magnetic sensor.
    [3" id="c-fr-0003]
    3. The depth positioning method according to claim 2, in which the step of determining (S14) a depth offset (DEPTH SHIFT) comprises:
    - a first optimization loop scanning depth offset values (DEPTH_SHIFT (j)) and determining the depth offset (DEPTH_SHIFT) which corresponds to a maximum of correlation; and
    - a second optimization loop scanning values of depth window (DWk) between a depth window (DW 0 ) of several tens of meters and a depth window (DWf) of a few meters.
    [4" id="c-fr-0004]
    4. The deep positioning method according to claim 1, when the reference set of magnetic measurements is generated by the second passive magnetic sensor separated from the first passive magnetic sensor by the given distance (DS) deployed and moved in the well. hydrocarbons simultaneously, further consisting of:
    - determining (S4, S4 ') a flight time between the two sets of magnetic measurements by determining the maximum correlation in a sliding time window (TW k );
    - calculate (S5) a speed of the first passive magnetic sensor along the deep portion of the oil well;
    - calculating a depth log (S6) based on said speed and an initial reference position (DEPTHO); and
    - generate (S7) a reference magnetic log (MAG_R) by correcting a depth positioning scale of the first set of magnetic measurements based on said depth log.
    [5" id="c-fr-0005]
    5. The deep positioning method according to claim 4, in which the step of determining (S4, S4 ') a time of flight (TF (i)) comprises:
    - a first optimization loop scanning time of flight values (tfj) and determining the time of flight (TF (i)) which corresponds to a maximum of correlation; and
    a second optimization loop scanning time window values (TW k ) comprised between a time window (TW 0 ) of several tens of seconds and a time window (TWf) of a few seconds.
    [6" id="c-fr-0006]
    6. The deep positioning method according to claim 4, further comprising:
    generating (S1 S2 ′, S3) a first set of positioning measurements associated with the set of magnetic measurements of the first passive magnetic sensor, and a second set of positioning measurements associated with the set of magnetic measurements of the second passive magnetic sensor, both sets of positioning measurements being generated by a first positioning sensor and a second positioning sensor in proximity to the first passive magnetic sensor and the second passive magnetic sensor that are deployed and moved in the oil well simultaneously, respectively;
    - calculate (S6) the magnetic measurements in a cylindrical or spherical coordinate system; and
    - generate (S7 ') a magnetic reference log as a function of the radial distance p, the azimuth φ and the height z selorèrhe system of cylindrical coordinates, or the radius r, of the elevator) and the azimuth φ according to the spherical coordinate system.
    [7" id="c-fr-0007]
    7. Use of the depth positioning method according to any one of claims 1 to 6, in order to determine a speed of a production logging tool deployed and moved in the hydrocarbon well along the depth portion of the oil well, the production logging tool comprising at least two passive magnetic sensors.
    [8" id="c-fr-0008]
    8. Use of the depth positioning method according to any one of claims 1 to 6, in order to determine a density of the wellbore fluid flowing in the depth portion of the oil well by correcting the scale of positioning in depth of a pressure gradient measurement log obtained from a pressure sensor and calculating the density by dividing the pressure gradient by earth gravity, possibly corrected by the cosine of the inclination d '' an oil well in case of an inclined oil well.
    [9" id="c-fr-0009]
    9. Use of the depth positioning method according to any one of claims 1 to 6, in order to evaluate the integrity of the oil well by comparing the reference clearance of the magnetic measurements taken previously corresponding to a casing of a non-well damaged, to a subsequent set of magnetic measurements indicating magnetic anomalies corresponding to damaged well casing and connecting said anomalies to depths having portions of damaged well casing.
    [10" id="c-fr-0010]
    10. A deep positioning device (11) for positioning a production logging tool (1, 40) and a measurement logging in a hydrocarbon well (3) in production obtained by means of said tool, the deep positioning (11) comprising:
    - a first passive magnetic sensor (28) designed to generate a set of magnetic measurements of a depth portion of the oil well, the set of magnetic measurements comprising numerous measurements of amplitude and / or direction of the magnetic field which forms a characteristic magnetic field pattern representative of a surrounding magnetic field of the oil well along the depth portion;
    - Means for deploying and moving the first passive magnetic sensor along the deep portion of the oil well;
    - a processing unit (29):
    • designed to compare said set of magnetic measurements with another set of magnetic measurements, the other set of magnetic measurements being a reference set of magnetic measurements generated either by an identical or similar passive magnetic sensor deployed and moved previously in the well d hydrocarbons, either by a second passive magnetic sensor, separated from the first passive magnetic sensor by a given distance (DS), so as to be deployed and moved in the oil well simultaneously, and • designed to determine the maximum correlation between the magnetic measurement set and the magnetic measurement reference set, said maximum being linked to the characteristic magnetic field pattern identifiable on a part of the depth portion.
    [11" id="c-fr-0011]
    11. The deep positioning device according to claim 10, further comprising a first positioning sensor (32) near the first passive magnetic sensor (28) and a second positioning sensor near the second passive magnetic sensor.
    [12" id="c-fr-0012]
    12. The deep positioning device according to claim 10, comprising at least one electronic card (26) comprising a quartz oscillator (31), a memory (30), the passive magnetic sensor (28) produced in the form of a triaxial magnetometer chip, a positioning sensor (32) produced in the form of a triaxial accelerometer chip, the whole being connected to the processing unit (29) produced in the form of a microcontroller.
    [13" id="c-fr-0013]
    13. The deep positioning device according to claim 12, comprising two electronic cards positioned at the given distance (DS) from one another.
    [14" id="c-fr-0014]
    14. A production logging tool (1) comprising a depth positioning device according to any one of claims 10 to 13 and at least one sensor (5, 44) sensitive to at least one property of a mixture of 'multiphasic flow (F1, F2) flowing in the oil well (3) or at least one property of a formation (4) surrounding the oil well.
    [15" id="c-fr-0015]
    15. A recording ball (40) comprising a protective envelope (41) of a spherical shape having an average density allowing it to be driven along the hydrocarbon well with a mixture of multiphasic flow (F1, F2) s 'flowing in the hydrocarbon well (3), a battery (41), an electronic card (43) connected to at least one sensor (44) sensitive to at least one property of the multiphasic flow mixture or to at least one property of a
    15 formation surrounding the oil well and a depth positioning device (11) according to any one of claims 10 to 13.
    1/9
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    同族专利:
    公开号 | 公开日
    EP3263832A1|2018-01-03|
    US20180003032A1|2018-01-04|
    GB2552422A|2018-01-24|
    GB2552422B|2019-05-15|
    GB201710500D0|2017-08-16|
    FR3053382B1|2020-01-31|
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    法律状态:
    2018-06-12| PLFP| Fee payment|Year of fee payment: 2 |
    2019-05-21| PLFP| Fee payment|Year of fee payment: 3 |
    2020-06-16| PLFP| Fee payment|Year of fee payment: 4 |
    2021-06-09| PLFP| Fee payment|Year of fee payment: 5 |
    优先权:
    申请号 | 申请日 | 专利标题
    EP16177265.2|2016-06-30|
    EP16177265.2A|EP3263832A1|2016-06-30|2016-06-30|Method and device for depth positioning downhole tool and associated measurement log of a hydrocarbon well|
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