• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
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    • 专利摘要:
    method and apparatus for evaluating a cemented well drilling casing. the present invention relates to a method of evaluating a well drilling casing in a land formation includes: emitting at least one acoustic signal in the well drilling through an acoustic source and detecting a return acoustic signal through an acoustic sensor, the well drilling including a liner and a supporting liner material disposed between the liner and a well drilling wall; emission of a neutron flux through a neutron source in the well drilling and detection of a radiation signal through a radiation detector, the radiation signal including induced gamma radiation resulting from neutron interactions; and identifying a characteristic support lining material based on the return acoustic signal and the radiation signal.
    公开号:BR112012025644B1
    申请号:R112012025644-0
    申请日:2011-04-06
    公开日:2020-03-10
    发明作者:David M. Chace；Rafay Z. Ansari；Elton Frost
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    Descriptive Report of the Invention Patent for "METHOD AND APPARATUS FOR ASSESSING A WELL HOLE COATED IN A TERRESTRIAL FORMATION".
    Cross Reference for Related Applications [0001] This application claims the benefit of an earlier filing date of United States Provisional Order No. 61/321, 637 filed April 7, 2010, the full description of which is incorporated here by reference .
    Background [0002] Well drilling production survey used in underground operations typically uses coatings arranged in it to protect well drilling from drilling pressures, chemical reactions and other conditions and prevent failures such as well drilling collapse, rupture and traction failures. Coatings can also be used to define production zones in various portions of the well drilling.
    [0003] Coating monitoring and evaluation techniques are important tools in maintaining the integrity of the coating, and in turn maintaining the integrity of the well drilling. Typical assessment and maintenance procedures involve asking which liner and cement is used to attach the liner to a well drilling wall to determine whether voids are present between the liner and the well drilling wall.
    [0004] Typical methods for detecting voids include asking the coating and cement with acoustic signals to detect micro ring and other openings formed between the coating and the well drilling wall. Detected micro-rings are typically corrected using methods such as applying hydrostatic pressure to the inside of the coating. Such detection methods can be ineffective and inaccurate in that they may be unable to effectively differentiate between an insignificant micro-ring and a real void between the coating and the cement that can compromise the hydraulic seal formed between them.
    Summary [0005] A method of evaluating a well drilling casing in an earth formation includes: emitting at least one acoustic signal in the well drilling through an acoustic source and detecting a return acoustic signal using an acoustic sensor , well drilling including a liner and a supporting liner material disposed between the liner and a well drilling wall; emitting a neutron stream through a neutron source in the well drilling and detecting a radiation signal through a radiation detector, the radiation signal including induced gamma radiation resulting from neutron interactions; and identifying a characteristic support lining material based on the return acoustic signal and the radiation signal.
    [0006] A method of evaluating a well drilling casing in a land formation includes: elimination of an acoustic measurement device in the well drilling casing, the well drilling including a liner and a supporting liner material disposed between the casing and a well bore wall, the acoustic measuring device including from at least one acoustic source and at least one acoustic receiver; emission of an acoustic signal when drilling a well in a plurality of locations and detection of an acoustic return signal in each of the pluralities of locations; generating an acoustic register that includes a plurality of return signal amplitudes, each return signal amplitude correlated with a respective location; identifying a gap location in the backing material by comparing at least one of an amplitude and an attenuation of each return signal amplitude to a reference value; elimination of a neutron measuring device in the well drilling casing, the neutron measuring device including at least one neutron source and at least one gamma ray detector; emitting a neutron stream in the well drilling in the plurality of locations and detecting a radiation signal in each of the pluralities of locations, the radiation signal including induced gamma radiation resulting from neutron interactions; generation of a neutron register that includes a plurality of radiation counts, each radiation count corresponding to a concentration component in each of the plurality of locations; determining the radiation count at the location of the gap and comparing the radiation count at the location of the gap to a reference radiation; and identify whether the gap is a void based on comparison.
    [0007] An apparatus for evaluating a well drilling casing in an earth formation includes: an acoustic measuring device configured to be arranged in the well drilling casing and including at least one acoustic source configured to allow at least one signal acoustic in well drilling and at least one acoustic sensor configured to detect an acoustic feedback signal, the well drilling including a liner and a supporting liner material disposed between the liner and a well drilling wall; a neutron measuring device configured to be arranged in the well drilling casing and including at least one neutron source configured to allow neutron flux in the well drilling and at least one radiation detector configured to detect a radiation signal , the radiation signal including induced gamma radiation resulting from neutron interactions; and at least one processor configured to receive at least one feedback beep, analyze the feedback beep to estimate a gap location in the backing material, analyze the radiation signal to estimate the concentration of a component of the material support coating, and identify whether the gap is a defective portion in the support coating material based on the concentration of the component in the location.
    Brief Description of the Drawings [0008] The subject that is considered to be the invention is particularly shown and distinctly claimed in the claim at the conclusion of the specification. The background and other characteristics and advantages of the invention are apparent from the detailed description below taken in conjunction with the accompanying drawings in which: Figure 1 is a lateral cross-sectional view of an underground well drilling modality, evaluation, exploration and / or production system; figure 2 is a lateral cross-sectional view of a modality of a drilling tool for the evaluation of a well drilling through the measurement of the induced neutron activation signal; figure 3 is a lateral cross-sectional view of a modality of a drilling tool for acoustic evaluation of a well borehole; figure 4 is a flowchart providing an exemplary method of evaluating a well drilling casing in a land formation; and figures 5A and 5B are illustrations of an exemplary pulsed neutron register and an exemplary cement to connect the register, respectively, generated together with the method of figure 4.
    Detailed Description [0009] Apparatus and methods for assessing well borehole liner materials are described here. The apparatus and methods include the use of acoustic cement assessment techniques in combination with neutron measurements to estimate properties of well borehole liner materials and / or assess the integrity of a wellbore liner assembly. In one embodiment, the apparatus and methods combine acoustics and neutron measurements to detect gaps, voids or other significant deficiencies or defective portions in the well drilling support liner and / or bonding materials, such as cement.
    [00010] Referring to figure 1, an exemplary embodiment of underground well drilling, evaluation, exploration and / or production system 10 includes a well drilling chain 12 which is shown arranged in a well drilling 14 that penetrates at least one earth formation 16 during an underground operation. As described here, a "formation" refers to various characteristics and materials that can be found in an underground environment and surround well drilling 14. A liner 18 disposed in well drilling 14 and is cemented or bonded to the drilling wall through a support liner material such as cement 20 that includes any suitable cement or other material sufficient to bond the liner 18 to the well bore wall, facilitate the coating on the support and / or insulating portions of the well bore 14, or otherwise support the coating. In one embodiment, the backing material is a cement material that includes silicon.
    [00011] The coating 18 is made of any material suitable to withstand sounding conditions such as pressure, temperature and chemical action. Examples of such materials include steel, heat-treated carbon steel, stainless steel, aluminum, titanium, fiberglass and other materials. In one embodiment, the liner 18 includes a plurality of pipe segments or liner joints connected together via threaded joints or other mechanisms and connections. The liner 18 can extend to any length of the well bore. For example, well drilling 14 may include a complete coating extending from a surface or surface location close to a selected depth or a liner such as a liner production that is suspended in well drilling 14. Cement 20 includes a material or mixture that is forced into a space between liner 18 and well bore 14 and serves to bond liner 18 to the wall of the well bore.
    [00012] In one embodiment, the well drilling chain 12 includes a drilling tool 22 such as a well recording tool. In one embodiment, the drilling tool 22 is configured as a coating / cement assessment tool. The drilling tool 22 is shown in figure 1 as a plumbing tool, but is not limited to it, and can be arranged with any suitable carrier. A "carrier" as described here means any device, device component, combination of devices, media and / or member that can be used to transmit, cause, support or otherwise facilitate the use of another device, device component, combination devices, media and / or member. Exemplary non-limiting carriers include well-drilling chains of the spiral tube type, the articulated tube type and any combination or portion thereof. Other carrier examples include casing tubes, plumbing, plumbing probes, slickline probes, experimental drop, underwater drilling, hole base assemblies, and drill chains.
    [00013] The drilling tool 22, in one mode, is configured as a neutron measurement tool and / or an acoustic interrogation tool. Tool 22 includes at least one interrogation source 24 and at least one detector 26. In one embodiment, electronics 28 is also included for storing, transmitting and / or processing signals and / or data generated through at least one detector 26 The number of sources 24 and detectors 26 is not limited.
    [00014] In one embodiment, at least one source 24 is at least one acoustic source and at least one detector 26 is at least one acoustic detector. In another embodiment, at least one source 24 is at least one neutron source and at least one detector 26 is at least one radiation detector such as a gamma ray and / or neutron detector. In another embodiment, a tool 22 includes sensors and detectors to ask for coating 18, cement 20 and / or formation 16 with both acoustic signals and neutron flow emissions.
    [00015] In one embodiment, tool 22 is equipped with transmission equipment to finally communicate to a surface processing unit 30. Such transmission equipment can take any desired shape, and different transmission media and methods can be used. Examples of connections include wired, fiber optic, wireless and memory-based systems.
    [00016] Figure 2 illustrates an exemplary modality of tool 22, in which tool 22 is configured as a neutron measurement tool 23. In this modality, at least one interrogation source 24 includes at least one neutron source 32 and at least at least one detector 26 includes one or more gamma ray detectors 34, 36. The neutron source 32 is configured to allow high energy neutrons (ie, a neutron flux) at selected well drilling locations over selected time periods . The neutron flux can be generated as a pulsed emission. The neutron source can be any suitable device that emits neutrons. Examples of neutron sources include pulsed neutron sources and chemical neutron sources such as Americium-Beryllium (AmBe) sources. Two of the main interaction mechanisms that are detected by the gamma ray detector 34, 36, among others, are neutron capture and inelastic neutron scattering that can generate induced neutron gamma rays.
    [00017] In one embodiment, the gamma ray detector 34, 36 is configured to detect gamma ray photons emitted naturally from well drilling 14 and formation 16, as well as gamma ray photons generated from neutron interactions with core in well drilling 14 and formation 16. Photon detection includes counting the photons, measuring the energy of each detected photon, and / or measuring the detection time in relation to the time of each neutron pulse. Thus, the gamma ray detector 34, 36 can acquire data that can be used to provide a time spectrum and / or an energy spectrum. In one embodiment, at least one detector 26 also includes one or more neutron detectors, for example, to measure the flow of neutrons to correct the detected silicon activation and compensate for changes in neutron output.
    [00018] In one embodiment, the radius detector ranges 34, 36 includes a first or main detector 34 located at a selected distance "Dl" above a hole from the neutron source 32 and a second or leak detector 36 located at a selected distance "D2" polling from the neutron source 32. As described here, "uphole" refers to a location on tool 23 that is closest to the surface relative to a reference location when tool 23 is arranged on well drilling 14. Likewise, "drilling" refers to a location on tool 23 that is furthest from the surface relative to the location reference when tool 23 is arranged in well drilling 14. In one embodiment, D1 and D2 are at least less substantially equal in magnitude, although D1 and D2 may be different. For example, the main detector 34 and the leak detector 36 can each be located approximately 10 feet from the neutron source 32. The number and location of the radius detector ranges 34 and 36 are not limited.
    [00019] In one embodiment, the main detector 34 is configured to naturally detect the occurrence of radiation emitted from formation 16 when the tool 23 is arranged in and / or advanced through the well drilling, and the leak detector 36 is configured to detect radiation emitted from formation 16 as a result of the occurrence of natural radiation and interactions between neutron emission and the core in well drilling 14 and formation 16. As described here, a "main" position refers to a location on tool 23 that reaches a reference location before the neutron source 32 as tool 23 moves through well bore 14. Likewise, an "escape" position refers to a location on tool 23 that reaches a location reference after the neutron source 32 as tool 23 moves through well drilling 14.
    [00020] Although the neutron measurement tool 23 shown in figure 2 includes multiple detectors, the type and configuration of the neutron 23 tool described here are not limited. For example, tool 23 can include only a single detector and gamma ray measurements can disregard the effect of the occurrence of natural neutron. In another example, tool 23 is configured as multiple tools or submarines, each having at least one respective source and / or detector arranged here. Tool 23 may include any number of sources and detectors such as a detector array and / or detectors positioned at multiple radial and / or circumferential locations on or over tool 23.
    [00021] Referring to figure 3, in one embodiment, tool 22 is configured as an acoustic measurement tool 37. In one embodiment, acoustic measurement tool 37 is configured to measure coating properties 18 as well as cement 20 In one embodiment, the acoustic measuring tool 37 is configured to measure properties relating to the characteristics of the connection between the coating 18 and the cement 20.
    [00022] At least one source 24, in this embodiment, is an acoustic source 38 configured to allow sonic or other acoustic waves within the liner 14, the cement 20 and / or the formation 14. Examples of acoustic sources include piezoelectric devices, acoustic transmitters electromagnetic devices, pulsed laser devices, flexion resonators, wedge transducers and combinations thereof. At least one detector 26 is configured as one or more acoustic receivers 40, 42 configured to detect reflected acoustic waves. In the embodiment shown in figure 3, two detectors 40, 42 are illustrated. However, any number of detectors 40 can be positioned at various locations on or over tool 37. For example, an array of detectors can be positioned at multiple locations along the length of the tool and / or a multiple angular location to affect a set two-dimensional or three-dimensional data.
    [00023] In an example, illustrated in figure 3, the acoustic measurement tool 37 includes a first acoustic detector 40 positioned at a first distance D1 from acoustic source 38 and a second acoustic detector 42 positioned at a second distance greater D2 a from acoustic source 38. Exemplary distances for Dl and D2 are 3 feet and 5 feet, respectively. The first acoustic detector 40 can be configured to detect amplitudes of reflected wave in general corresponding to a close area for an interface between the coating 18 and the cement 20 (i.e., the "cement coating / bond"), and the second detector acoustic 42 can be configured to detect reflected wave in general corresponding to an area close to an interface between cement 20 and formation 14 (i.e., the "formation cement / bond").
    [00024] Figure 4 illustrates a method 50 of evaluating a well drilling casing. The method can be used to identify characteristics of cement 20 and / or evaluate the integrity of the bond between coating 18 and cement 20. In one embodiment, method 50 is a method of identifying characteristics of cement 20. Such characteristics may include or be indicative of voids and other defective portions of the cement, such as areas of separation or displacement between the liner 18 and the cement 20 that are significant enough to allow the flow of drilling fluids into it and compromise a hydraulic seal formed between the liner 18 and cement 20. In one embodiment, "defective portions" refer to those portions of cement 20 that include areas of separation between liner 18 and cement 20, areas of reduced cement thickness or other characteristics that allow fluid to flow through of the same. Such defective portions can compromise the production integrity of the zones formed in the drilling of well 14 through casing 18. Another characteristic includes the type and / or quantity of material components (for example, silicon) in the cement.
    [00025] Method 50 can be performed in conjunction with system 10, the neutron tool 23, the acoustic tool 37 and / or a tool 22 or sounding assembly includes both neutron and acoustic measurement capabilities, but does not is limited to the same. Method 50 can be used in conjunction with any device or configuration capable of taking neutron / gamma rays and acoustic measurements. Method 50 includes one or more stages 51-56. In one embodiment, method 50 includes performing all stages 51-56 in the order described. However, certain stages can be omitted, stages can be added, or the order of stages changed. [00026] In one embodiment, taking measurements with the neutron 23 tool (which includes a neutron source such as a chemical source or pulsed neutron), the acoustic tool 37 and / or other tools is recorded in relation to the depth and / or position of tool 22, which is referred to as a "register", and a register of such measurements is referred to as a "register". Exemplary registers include a cement to bond register (CBL) generated through the acoustic tool 37 and a neutron register generated through the neutron tool 23. Additional examples of registration processes include registration measurements after drilling, plumbing registration, drilling operations transmission tube record, experimental drop record and memory record. The data recovered during these processes can be transmitted to the surface such as to the surface processing unit 30, and can also be stored with the tool (via, for example, electronics 28) for later recovery.
    [00027] In the first stage 51, an acoustic measurement tool such as the acoustic tool 37 is arranged in the drilling of well 14. In one embodiment, the acoustic tool 37 is reduced in the drilling of well 14 through a pipe, even though the acoustic tool 37 can be reduced by any suitable mechanism.
    [00028] The acoustic source 38 is activated and an acoustic signal is emitted at least in the coating 18 and the cement 20. The acoustic waves emitted as part of the acoustic signal travel through the coating 18, the cement coating / connection, the cement 20 , the cement / bonding formation and / or the formation 14. Examples of acoustic waves include ultrasonic waves such as a Lamb wave and cut horizontal waves, compression waves and P waves.
    [00029] One or more receivers 40, 42 detects reflected waves from various locations in well drilling 14 and / or formation 16 as acoustic feedback signals. Such locations include, for example, the coating / cement to bond and the forming cement / bond. These events can be recorded as acoustic data in the form of, for example, wave spectra having various patterns. [00030] In the second stage 52, the acoustic feedback signals are analyzed to determine parameters as well as the condition of the cement and / or the cement / coating connection. This analysis can include recording the return signals over time and then correlating the depth as well as processing the associated data to produce a record (for example, a CBL) or another measurement record. Examples of useful data include the time and amplitude of both emitted and recorded waves, signal amplitude and time delay values. In addition, wave attenuation such as the wave propagated through the coating 18 and the cement 20 can be etched. [00031] For example, the amplitudes and / or attenuations of received acoustic signals are compared at different locations and / or at locations corresponding to multiple receivers in a matrix. An increase in the recorded attenuation indicates some kind of inconsistency, which can be considered as a possible identification of a significant void or other defective portion in the cement. Such an inconsistency, such as a micro ring, may be indicative of a significant defective portion, or it may represent only an inconsequential feature of the cement.
    [00032] For example, a larger return signal amplitude recorded by a receiver 40, 42 is identified as identifying a gap such as a micro ring between the liner 18 and the cement 20 and / or between the cement 20 and the formation 14. This gap may be an indicator of a potential defective portion or "bad bond" in the cement 20 that can compromise the cement lining / bond. A smaller range of signals is identified as identification that there is no gap and thus is an indicator of a "good connection" between the coating 18 and the cement 20.
    [00033] Gap identification includes, in one mode, comparison of the acoustic feedback signal with a reference value. For example, a reference attenuation and / or amplitude value is selected which indicates a value at or above which indicates a potential bad connection. This reference value can be selected from a known amplitude and / or attenuation value to indicate a good connection based on previous measurements or an estimated average amplitude and / or attenuation from and an acoustic record.
    [00034] In the third stage 53, a neutron 23 tool such as a chemical source or pulsed neutron tool is arranged in the well bore 14, and the neutron source 32 is activated to allow high energy neutrons in the coating 18, the cement 20 and / or formation 14. Radiation detectors 34, 36 detect radiation including gamma rays emitted from the coating 18, cement 20 and / or formation 14. In one embodiment, one or more measurements are taken for each one of a plurality of well drilling locations and / or depth to generate the neutron record. Activation and detection are carried out at multiple depths, and can be performed while the neutron 23 tool is in motion, for example, being pulled uphole through a selected section of well drilling 14 at a selected speed. An exemplary recording speed is 10 ft / min in the uphole direction for the 10-foot exemplary Dl spacing with the main neutron source 32 from at least one detector 34, 36. As described here, "neutron measurements" and "recordings of neutron" neutron "refers to measurements of radiation that includes radiation resulting from the interaction of neutrons emitted with elements in well drilling and / or formation.
    [00035] In one embodiment, the main gamma ray detector 34 detects natural gamma radiation from component materials such as silicon, potassium, uranium and thorium. The leak detector 36 detects gamma rays that include natural radiation as well as gamma rays resulting from interactions between the emitted neutrons and core (such as silicon core in cement and formation) in coating 18, cement 20 and / or training 16.
    [00036] In the fourth stage 54, gamma ray signals detected by the leak detector 36 are analyzed to generate inelastic, thermal neutron capture, and / or neutron gamma ray activation. The spectrum is analyzed, for example, by counting gamma rays in the windows placed on the main peaks for the elements involved, or by comparing them with known patterns, or by combining the two.
    [00037] In one embodiment, the concentration of one or more elements, such as oxygen and silicon, are determined by measuring the activation of neutron gamma counting radiation rates recorded by the radius detector ranges 34, 36. For example, concentrations of elements are identified by recording to the radiation rate count (for example, at the American Petroleum Institute (API units)) which several with the half life of the elements. In one embodiment, a gamma ray count rate on silicon activation (ie, an amount of gamma rays generated due to silicon activation through neutrons, referred to here as a "silicon activation count rate") is generated the identification of a concentration of silicon in cement 20 and / or formation 16, corresponding to a number and depth and / or locations in well drilling 14. A counting rate on recorded or recorded silicon activation can be constructed. Although the analyzes described here refer to the measurement of silicon concentration, the analyzes can refer to any number of measurements, such as concentrations of elements including iron, oxygen, and any other element capable of being activated by fast neutrons.
    [00038] In one embodiment, the count rate on activation of silicon is generated by comparing the natural radioactivity count rate (ie natural count rate) detected by the main detector 34 with the natural radioactivity plus count rate silicon (ie, leakage count rate) detected by leak detector 36. For example, the main count rate is subtracted from the leak count rate to generate an indicative count rate of the silica behind the liner 18 in cement 20 and formation 16. The silicon count rate can be attributed to silica-filled cement rings by adding additional counts. In another modality, the main detector is excluded, and the counting rate on silicon activation is generated without accounting for natural radioactivity.
    [00039] The counting rate on silicon activation is proportional to the volume of cement in the ring between coating 18 and formation 16 at an average depth, and can also be proportional to the amount of silicon in formation 16. Variations in the amount of silicon they are saved by comparison with a reference value or level such as a reference or base count rate. The count rate reference can be selected rate considered to be related to a volume of cement, or it can be based on the count rate measured on silicon activation. For example, the count rate reference is an average of the count rate on silicon activation measured at various depths during well drilling 14. For example, the count rate on silicon activation measured by various depths may be in the range of between zero and over 1000 API units. A potentially significant drop in the count rate, that is, a potential void, can be on the order of over 100 API units.
    [00040] Although stages 51 and 53 are described as being performed separately, for example, in separate registration runs, stages 51 and 53 can be performed as a single step. For example, the well drilling chain 12 can include both acoustic and neutron tools, and acoustic and neutron measurements are performed during the same record run. In another example, acoustic and neutron measurements can be collected through a single probe tool 22 configured to take both acoustic and neutron measurements.
    [00041] In the fifth stage 55, measurements from the neutron tool 23 and the acoustic tool 37 are compared to evaluate the coating 18 and / or the cement 20. For example, a cement to bond register is compared to a count rate activating the silicon register to identify defective portions or bad bonds in cement 20.
    [00042] In one embodiment, assessment includes identifying locations of potential bad connections from the cement to bond record (CBL). A counting rate on activation of the silicon register is then used to identify measurements of silicon concentration at identified locations corresponding to potential bad binding located from the CBL. Inspection of the silicon concentration measurements at the identified locations can be used to determine whether the indication of the potential bad bond is a micro ring (a minimal gap that does not have a significant effect on the integrity of the coating / cement) or is it really a void or another defective portion in the cement 20.
    [00043] The count rate on silicon activation at the identified locations is analyzed to determine without a significant deviation in the count rate on silicon activation occurred at the location, which would indicate the presence of a defective portion. In one embodiment, a significant deviation is selected as a drop in the silicon activation count rate to a level below a base or reference level, such as an average silicon activation count value. If the count rate at activation of silicon at an identified location exposes a significant deviation, the change in composition in which the location is considered to be indicative of a void in the cement behind the coating, in contrast to just a micro ring.
    [00044] Alternatively, if the count rate on silicon activation is within a range selected from the reference level, the "potential" bad bond is considered to be only a micro ring or other insignificant characteristics, which do not require any mediation or corrective measure.
    [00045] In the sixth stage 56, if a bad or empty link is identified, corrective measures are employed to repair a bad link. Examples of such corrective measures include conventional repair cement such as cemented pressure.
    [00046] Figures 5A and 5B illustrate an example of an acoustic register 60 and a pulsed neutron register 62 that can be used in method 50. The acoustic register in this example is a CBL showing acoustic attenuation values. Regions 64 and 66 are shown in the acoustic register 60 as being potential bad connections, due to a drop in attenuation in these regions. Comparison of the silicon activation count from the pulsed neutron record 62 at the locations corresponding to regions 64 and 66 shows a drop in the silicon activation count only in region 64, and thus only region 64 is identified as a defective portion. Thus, the use of both the acoustic register 60 and the pulsed neutron register 62 as described in the methods above provides a more accurate identification of current defective cement portions.
    [00047] The devices and methods described here have several advantages over the devices and techniques of the prior art. The devices and methods allow accurate detection of bad connections in the well drilling casing, and also allow effective differentiation between micro rings that do not significantly affect the integrity of the coating / cement connection from voids or thin cement areas that compromise hydraulic stability. . In addition, the devices and methods described here eliminate the need to employ unnecessary repair measures in the coating regions that may have hydraulically insignificant micro rings.
    [00048] In addition, the devices and methods provide a simplified technique for detecting bad connections. For example, some prior art methods for identifying bad connections include performance of a first acoustic record run in the well drilling at a first hydrostatic pressure, followed by the introduction of additional fluid into the well drilling at a second hydrostatic pressure greater than enough to apply the pressure and reduce or eliminate the micro ring or other gaps in the cement. A second acoustic record run is performed while the well drilling is under the second hydrostatic pressure. The signals for the first and second register runs are compared to identify micro ring or other inconsistent locations that show a significant improvement in signal amplitude between corresponding first and second beeps. The devices and methods described here do not require such pressurization techniques to identify bad connections.
    [00049] In connection with the teachings here, various analyzes and / or analytical components can be used, including digital and analog systems. The system may have components such as a processor, storage medium, memory, input, output, communication links (wired, wireless, pulsed mud, optical or other), user interfaces, software programs, signal processors ( digital or analog) and other such components (such as resistors, capacitors, inductors and others) to provide for operation and analysis of the apparatus and methods described here in any of several ways well appreciated in the art. It is considered that these teachings can be, but need not be, implemented in conjunction with a set of executable computer instructions stored on a computer readable medium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic ( disks, hard disks), or any other type that when executed causes a computer to implement the method of the present invention. These instructions may provide for equipment operation, control, data collection and analysis and other functions deemed relevant for a designed system, owner, user or other personnel, in addition to the functions described in this description.
    [00050] A person skilled in the art will recognize that the various components or technologies may provide certain necessary or beneficial functionalities or characteristics. In this way, these functions and features, as may be necessary in support of the attached claim and variations thereof, are recognized as being naturally included as a part of the teachings here and a part of the description of the invention.
    [00051] While the invention has been described with reference to exemplary modalities, it will be understood by those skilled in the art that various changes can be made and equivalents can be replaced by elements of the same without departing from the scope of the invention. In addition, many modifications will be appreciated by those skilled in the art to adapt a particular instrument, situation or material to the teachings of the invention without departing from its essential scope. For this reason, it is understood that the invention is not limited to describing the particular modality as a better contemplated way of carrying out this invention.
    权利要求:
    Claims (20)
    [1]
    1. Method for evaluating a well hole (14) coated in a terrestrial formation (16), characterized by comprising: emission of at least one acoustic signal in the well hole (14) through an acoustic source and detection of a signal acoustic feedback via an acoustic sensor, where the well hole (14) includes a liner (18) and a liner support material (20) disposed between the liner (18) and a well hole wall (14 ); o at least one acoustic signal configured to indicate a location of an empty space in the liner support material, the space being one of the following: an annular space formed between the liner and the well wall that is insignificant in relation to the integrity of a hydraulic seal formed between the box and the box support material and an empty space that can compromise the integrity of the hydraulic seal; emission of a neutron flux through a neutron source (32) in the well bore (14) and detection of a radiation signal through a radiation detector, in which the radiation signal includes induced gamma radiation resulting from interactions of neutrons and indication of characteristics of the coating support material (20); and identify whether the empty space in the liner support material (20) is an annular space that is insignificant in relation to the integrity of the hydraulic seal or if the gap is a void that can compromise the integrity of the hydraulic seal, based on the acoustic signal return and the radiation signal.
    [2]
    2. Method according to claim 1, characterized in that the characteristic is indicative of a defective portion of the supporting portion of the coating material.
    [3]
    3. Method, according to claim 1, characterized by the fact that identifying the characteristic includes: analysis of the acoustic feedback signal to estimate the location of a gap in the coating support material (20); analysis of the radiation signal to estimate a concentration of a constituent of the coating support material (20); and identifying whether the gap is a defective portion in the liner support (18) based on the concentration of the constituent in the location.
    [4]
    4. Method, according to claim 3, characterized by the fact that the analysis of the acoustic feedback signal includes calculation of at least one amplitude and an attenuation of the acoustic feedback signal and correlation of at least one amplitude and attenuation to a location in the well hole (14).
    [5]
    5. Method, according to claim 4, characterized by the fact that the analysis of the acoustic signal of return includes comparison of at least one among the amplitude and the attenuation for a reference value.
    [6]
    6. Method, according to claim 5, characterized by the fact that the analysis of the acoustic feedback signal includes identification of the gap if at least one between the amplitude and the attenuation is greater than the reference value.
    [7]
    7. Method according to claim 3, characterized by the fact that the radiation includes natural gamma radiation, and evaluation of the radiation signal includes subtraction of the natural gamma radiation from the induced gamma radiation.
    [8]
    8. Method, according to claim 3, characterized by the fact that the constituent is selected from at least one silicon, oxygen, iron, and any element capable of being activated by fast neutrons.
    [9]
    9. Method according to claim 3, characterized by the fact that identification if the gap is a defective portion includes: determining that the gap is not a defective portion if the concentration of the constituent is equal to or greater than a reference value in location; and determining that the gap is a defective portion if the concentration of the constituent is below a reference value at the location.
    [10]
    10. Method according to claim 9, characterized by the fact that the neutron flux is emitted and the radiation signal is detected in a plurality of locations, and the reference value is an average concentration of constituent over the plurality of locations.
    [11]
    11. Method, according to claim 3, characterized by the fact that the analysis of the radiation signal includes the measurement of a radiation count corresponding to a selected constituent and the correlation of the radiation count to a location in the well bore ( 14).
    [12]
    12. Method according to claim 3, characterized by the fact that the location is at least one of a well depth and a circumferential well location.
    [13]
    13. Method according to claim 1, characterized by the fact that the coating support material is a cement material.
    [14]
    14. Method for evaluating a well bore (14) coated in a terrestrial formation (16), characterized by comprising: provision of an acoustic measuring device (37) in the well bore (14), in which the borehole well (14) includes a liner (18) and a liner support material (20) disposed between the liner (18) and a well hole wall (14), in which the acoustic measuring device (37) includes at least at least one acoustic source and at least one acoustic receiver; emitting an acoustic signal in the well bore (14) in a plurality of locations and detecting a return acoustic signal in each of the plurality of locations; generating an acoustic register that includes a plurality of return signal amplitudes, in which each return signal amplitude correlates with a respective location; identification of a gap location in the lining support material (20) by comparing at least one of an amplitude and an attenuation of each amplitude of the return signal to a reference value, the space being one of the following: a space annular formed between the liner and the well wall which is insignificant in relation to the integrity of a hydraulic seal formed between the liner and the liner support material and an empty space that can compromise the integrity of the hydraulic seal; arranging a neutron measuring device (23) in the coated well bore (14), wherein the neutron measuring device (23) includes at least one neutron source (32) and at least one gamma ray detector; emitting a stream of neutrons into the well bore (14) in the plurality of locations and detecting a radiation signal in each of the pluralities of locations, wherein the radiation signal includes induced gamma radiation resulting from neutron interactions; generation of a neutron register that includes a plurality of radiation counts, each radiation count corresponding to a concentration of constituents in each of the plurality of locations; determining the radiation count at the gap location and comparing the radiation count at the gap location with a reference radiation count; and identification based on the comparison whether the space is an annular space formed between the liner and the well wall which is insignificant in relation to the integrity of the hydraulic seal formed between the liner and the liner support material, or whether the space is a that can compromise the hydraulic seal.
    [15]
    15. Method according to claim 14, characterized by the fact that the component is silicon.
    [16]
    16. Method according to claim 14, characterized by the fact that the reference radiation count is an average radiation count over the plurality of locations.
    [17]
    17. Apparatus for evaluating a well bore (14) coated in a terrestrial formation (16), characterized by comprising: an acoustic measuring device (37) configured to be arranged in the well bore (14) coated and including at least one acoustic source configured to allow at least one acoustic signal in the well hole (14) and at least one acoustic sensor configured to detect a return acoustic signal, well hole (14) including a liner (18) and a support material liner (20) disposed between liner (18) and a well hole wall (14); a neutron measuring device (23) configured to be disposed in the coated well hole (14) and which includes at least one neutron source (32) configured to emit a neutron stream in the well hole (14) and at least a radiation detector configured to detect a radiation signal, the radiation signal including induced gamma radiation resulting from neutron interactions; and at least one processor (30) configured to receive at least one acoustic feedback signal, analyze the acoustic feedback signal to estimate the location of a gap in the liner support material (20), the space being one of the following: one annular space formed between the liner and the well wall that is insignificant in relation to the integrity of a hydraulic seal formed between the liner and the liner support material and an empty space that can compromise the integrity of the hydraulic seal, analyze the radiation to estimate the concentration of a constituent of the liner support material (20), and to identify based on the radiation signal whether the gap is an annular space formed between the liner and the well wall that is insignificant in relation to the integrity of the hydraulic seal formed between the cover and the roof support material, or if the gap is a void that can compromise the seal hydraulic action.
    [18]
    Apparatus according to claim 17, characterized in that at least one radiation detector includes a main detector (34) configured to detect a natural radiation signal including natural gamma radiation, and a secondary detector (36) configured to detect an induced neutron activation signal that includes both natural gamma radiation and induced gamma radiation.
    [19]
    19. Apparatus according to claim 18, characterized by the fact that at least one processor (30) is configured to estimate the concentration of the constituent by comparing the natural radiation signal and the neutron-induced neutron activation signal.
    [20]
    20. Apparatus according to claim 17, characterized by the fact that the acoustic measuring device and the neutron measuring device are incorporated in a single conveyor.
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    同族专利:
    公开号 | 公开日
    GB2492693A|2013-01-09|
    US20120075953A1|2012-03-29|
    WO2011127156A2|2011-10-13|
    NO344936B1|2020-07-20|
    GB201218228D0|2012-11-28|
    BR112012025644A2|2016-06-28|
    US8964504B2|2015-02-24|
    WO2011127156A3|2012-04-05|
    GB2492693B|2015-05-20|
    NO20121217A1|2012-10-19|
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-10-08| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-01-28| B09A| Decision: intention to grant|
    2020-03-10| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 06/04/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US32163710P| true| 2010-04-07|2010-04-07|
    US61/321,637|2010-04-07|
    PCT/US2011/031403|WO2011127156A2|2010-04-07|2011-04-06|Method and apparatus for evaluating a cemented borehole casing|
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