• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    monitoring a condition of a component in a rotary control device of a drilling system using built-in sensors According to some embodiments of the present disclosure, a drilling system comprises a drill string and a rotary control device (rcd) associated with the drill string. the rcd includes a sealing member composed of an elastomeric material. a sensor is incorporated into the sealing element and detects a piercing condition associated with the rcd during a piercing operation. a control system determines wear of the sealing element based on the piercing condition.
    公开号:BR112015013681A2
    申请号:R112015013681-8
    申请日:2012-12-31
    公开日:2020-10-27
    发明作者:Raymond R. BULLOCK
    申请人:Halliburton Energy Services, Inc.；
    IPC主号:
    专利说明:

    [1] [1] The present disclosure refers generally to equipment used and operations performed in connection with well drilling operations and, more particularly, the monitoring of a component condition in a rotary control device of a drilling system using built-in sensors. FUNDAMENTALS
    [2] [2] When performing closed ring drilling operations, typically referred to as managed pressure drilling, under-balanced drilling, mud cover drilling, air drilling and fog drilling, a rotary control device (RCD), also called rotary drilling device, rotary drilling head, rotary flow diverter, pressure control and rotary ring device, can be used to divert drilling fluids that return from the well to chokes, separators and other equipment. The RCD can work to close the ring around a drill string during drilling operations. The RCD sealing mechanism, typically called as a sealing element or packer, is operable to maintain a dynamic seal on the ring, allowing chokes to control the ring pressure in surface drilling operations. The sealing element also allows drilling to continue while controlling the influx of forming fluids.
    [3] [3] The sealing element can be made of molded elastomeric packing material that includes different elastomeric compounds selected for different drilling applications. In some applications, the sealing element rotates with the drill pipe, and in other applications, the sealing element remains stationary, while the drill pipe rotates inside. As can be appreciated, the condition of the sealing element is important for the operation and continuous integrity of the RCD. However, the rotation and reciprocating movement of the drill pipe during drilling operations, often in conjunction with applied annular pressure, can cause the sealing element to wear out so that the seal provided by the sealing element becomes degrades over time.
    [4] [4] Conventional methods of monitoring wear on a sealing element can involve physical testing of the sealing element in a laboratory environment to determine the amount of sealing element degradation based on the number of drill pipe tool joint passes. and rotation speed of the drill pipes. The amount of degradation is then extrapolated to estimate how long the sealing element can be used in the field, either based on a maximum amount of time, maximum drill pipe rotation speed or the number of tool joint passes. of drill pipe. Wear and tear, however, can be unpredictable using this method due to varying surface conditions and the speed of reciprocating movement and rotation of the drill pipe. As a precautionary measure, the sealing element can be changed prematurely leading to costly interruptions to the drill rig. An unexpected failure of the sealing element can also lead to interruptions in the drilling probe and, in extreme cases, a release of pressure from the annular which can result in the flow of drilling fluids into the surrounding environment. BRIEF DESCRIPTION OF THE DRAWINGS
    [5] [5] For a more complete understanding of the present invention and its features and advantages, reference is now made to the following description taken in conjunction with the attached drawings in which:
    [6] [6] FIGURE 1 illustrates an example modality of a drilling system configured to perform closed annular drilling operations in accordance with some modalities of the present disclosure;
    [7] [7] FIGURE 2 illustrates a partial cross-sectional view of a rotary control device including sensors embedded in a sealing element in accordance with some embodiments of the present disclosure;
    [8] [8] FIGURE 3 illustrates a block diagram of a control system configured to receive measurements from the sensors embedded in the sealing element of the rotary control device of FIGURE 2 according to some modalities of the present disclosure; and
    [9] [9] FIGURE 4 illustrates a flowchart of an example method for monitoring a component condition on a rotary control device during drilling operations in accordance with some of the modalities of the present disclosure. DETAILED DESCRIPTION
    [10] [10] Modalities of the present invention and their advantages are best understood by reference to FIGURES 1 to 4, in which similar numbers are used to indicate similar and corresponding parts.
    [11] [11] FIGURE 1 illustrates an example modality of a drilling system configured to perform closed annular drilling operations in accordance with some modalities of the present disclosure. During closed ring drilling operations, also “referred to as managed pressure drilling, under-balanced drilling, mud cover drilling, air drilling and fog drilling, the drill column annular is closed using a device called a rotary control device (RCD), a rotary drilling device, rotary drilling head, rotary flow diverter, pressure control device and rotary ring. The main sealing mechanism of the RCD, termed as a sealing element or packer, seals around the drill string, thereby closing the annular around the drill string. During drilling operations, the sealing element may experience wear that degrades the seal provided by the sealing element. In order to minimize costly downtime for the drilling system when replacing the sealing element, sensors can be incorporated into the sealing element to monitor wear, degradation and vibration associated with the sealing element.
    [12] [12] As disclosed in more detail below and in accordance with some embodiments of the present invention, sensors can be incorporated into the sealing element during a molding process. In other embodiments, the sensors can be incorporated into the sealing element through drilled and sealed holes. The sensors can be nanosensors, fiber optic sensors and / or polymer fiber sensors that monitor various drilling properties including, but not limited to, deformation, pressure, temperature, fluid level, position, material loss and vibration. By monitoring the condition of the sealing element in real time during drilling operations, the use of the sealing element can be optimized in the field. For example, when wear is low and wear on the sealing element is minimal, the use of the sealing element can be extended to save downtime of the drilling system due to unnecessary remediation replacement of the sealing element. When the wear of the sealing element is high and the degradation of the sealing is accelerated, the sealing element can be replaced before a leakage event or loss of control occurs. Therefore, the use of sensors incorporated in the sealing element in accordance with the present disclosure can reduce the downtime of the drilling system and the cost associated with that downtime.
    [13] [13] drilling system 100 may include drilling unit 102, drilling column 104, rotary control device (RCD) 106, telescopic joint 108 of riser assembly
    [14] [14] Drilling unit 102 may include drilling floor 112 which is supported by various support structures (not expressly shown). The rotary table 114 can be located above the floor of the drill 112 and can be attached to the drilling column 104 to facilitate drilling a well hole using a drill bit (not shown expressly) attached to the opposite end of the drilling column. drilling 104. Drill column 104 can include multiple drill pipe sections that communicate drilling fluid from drilling unit 102 and provide torque for the drill bit. In the illustrated embodiment, the drilling fluid can be circulated back to the drilling unit 102 via the riser assembly
    [15] [15] In the illustrated embodiment, drilling column 104 can extend from drilling unit 102 through riser assembly 110 and into the underwater well hole (not shown expressly) formed on the ocean floor. A top portion of the RCD 106 can be coupled to the drilling unit 102 by an RCD riser above, mooring riser or telescopic joint, where the upper end of the riser or joint can be coupled to a diverter housing of the drilling unit ( not expressly represented). A sealing element or packer (not shown expressly) can be located inside the body of the RCD 106 and can be removed or inserted with the help of the latch assembly
    [16] [16] FIGURE 2 illustrates a partial cross-sectional view of RDC 106 including sensors embedded in a sealing element in accordance with some embodiments of the present disclosure. The RCD 106 can be used to seal the annular 202 formed radially between the body 204 of the RCD 106 and drill column 104 positioned inside the body 202. The RCD 106 can allow the drill column 104 to rotate and enter and exit the bore. well while maintaining pressure in annular 202. In the illustrated embodiment, bearing assembly 206 can be located in housing of bearing assembly 208. Sealing element 210 can be coupled to body 204 of RCD 106 by a mandrel (not shown expressly) ) connected to the bearing assembly 206, so that the sealing element 210 can rotate with the drill string
    [17] [17] sealing element 210 can form a seal around the drilling column 104 to close annular 202 and maintain pressure on annular 202 during drilling operations. In some embodiments, the sealing element 210 may be a molded device made of an elastomeric material. The elastomeric material can be composed including, but not limited to, natural rubber, nitrile rubber, hydrogenated nitrile, urethane, polyurethane, fluorocarbon, perfluorocarbon, propylene, neoprene, hydrine, etc. In one embodiment, sensors 212 can be incorporated into sealing element 210 during the molding process. In other embodiments, holes can be drilled in the sealing element 210 after the molding process is complete. The 212 sensors can be placed in the holes and the holes can be sealed to prevent drilling fluids from seeping into the holes.
    [18] [18] During drilling operations, the sealing element 210 and the bearings (not shown expressly) of the bearing assembly 206 may suffer wear due to the rotation and rotational movement of the drilling column 104. The sensors 212 embedded in the sealing element 210 can monitor various properties of the sealing element 210 and associated components of RCD 106, so that the rate and amount of degradation of the sealing element 210 and / or the bearings in the bearing assembly 206, and the vibration associated with the bearings bearing assembly 206 can be determined. For example, sensors 212 can monitor wear and / or condition of sealing element 210 by measuring drilling conditions, such as deformation, pressure, temperature, fluid level, position and material loss. In addition, sensors 212 can determine whether bearings in bearing assembly 206 are overloaded and / or worn by measuring the amount of vibration associated with bearing assembly 206 during drilling operations. Drilling operations may include, but are not limited to, drilling ahead, countersinking, countersinking, drilling pipe maneuver, drilling pipe separation, drilling pipe rotation and drilling pipe slip. Sensors 212 can communicate the measured drilling conditions to a control system (such as the control system illustrated in FIGURE 3) located on or remote to drilling unit 102 (as illustrated in FIGURE 1). As described in more detail with reference to FIGURE 3, the control system can correlate the drilling condition data to quantify and / or rate the wear of the sealing element 210 and the bearings of the bearing assembly 206, so that an operator can determine when to replace sealing element 210 and / or bearings in bearing assembly 206.
    [19] [19] Sensors 212 can be any suitable type of device that is configured to detect drilling conditions during drilling operations. In one embodiment, sensors 212 may be nanosensors that have at least one feature with a dimension in the nanoscale range. For example, the characteristic of the device may be pore diameter, wire diameter, platelet length, average particle diameter and the like. The substrate of sensors 212 can be in any way including, but not limited to, circular, elliptical and polygonal. Possible compositions for the material used to form the 212 sensors may include, but are not limited to, organic, inorganic, metallic, alloy, ceramic, conductive polymer, non-conductive polymer, ionic, non-metallic, ceramic- ceramic, ceramic-polymer, ceramic-metal, metal-polymer, polymer-polymer, metal-metal, metal salts, metal complexes, bio-organisms, biologically active materials, biologically derived materials, biocomposites or a combination of one or more of these. In other embodiments, sensors 212 may be formed of a polymer or optical fiber chain.
    [20] [20] Although FIGURE 2 illustrates a sensor incorporated in each of the sealing elements 210, any number of sensors can be incorporated in each sealing element 210. Additionally, sensors 212 can be layers incorporated in the sealing element 210 in wraps or circumferential loops, vertical loops, single or multiple layers, lattice networks, or any combination of detection paths to achieve a desired range of detection and monitoring.
    [21] [21] FIGURE 3 illustrates a block diagram of a control system configured to receive measurements from the sensors embedded in the sealing element of the rotary control device of FIGURE 2 according to some modalities of the present disclosure. In some embodiments, one or more sensors 212a-212i may be incorporated into the sealing element 210 of the RCD 106 in order to determine the wear and condition of the sealing element 210 during drilling operations.
    [22] [22] Sensors 212 can be configured to measure a number of drilling conditions associated with determining wear and / or sealing element condition 210 during drilling operations including, but not limited to, deformation, pressure, temperature , fluid level, position, material loss and vibration. 212 sensors can measure these conditions using any suitable methods including, but not limited to, resistance, capacitance, inductance, impedance, phase angle, loss factor, dissipation, breakdown voltage, electrical temperature coefficient of an electrical property, Nemst current, impedance associated with ionic conduction, open circuit potential, electrochemical property, electronic property, magnetic property, thermal property, mechanical property or optical property.
    [23] [23] The sensors 212 embedded in the sealing element 210 of the RCD 106 can be communicatively connected to the input device 302 of the control system 300, so that the control system 300 can receive the drilling condition data and other measured information by sensors 212. Input device 302 can direct data received from sensors 212 to data processing system 304. Processing system 304 may include a processor coupled to a memory. The processor may include, for example, a microprocessor, microcontroller, digital signal processor (DSP), application specific integrated circuit (ASIC) or any other digital or analog circuit configured to interpret and / or execute program instructions and / or process Dice. In some embodiments, the processor can interpret and / or execute program instructions and / or process data stored in memory. Such program instructions or process data may constitute pieces of software to perform simulation, monitoring or control of drilling operations.
    [24] [24] In some embodiments, the control system 300 can be configured to receive drilling conditions detected by sensors 212 incorporated in the sealing element 210 of the RCD
    [25] [25] Other wear indications can be made by monitoring the deformation measurements of the sealing element. As each drill pipe tool joint passes through RCD 106, the sealing element 210 can be forced to expand and contract to conform to the tool joint outside the diameter profile. When the sealing element 210 wears out reduced force (for example, deformation) it may be necessary to expand and contract the sealing element 210, thus indicating loss of material and wear on the sealing element 210. Likewise direct mass measurements of the sealing element and material loss can be an indication of wear. The measurements of sensors 212 can be correlated, for example, with the number of passes of the drilling tool joint, the number of hours of rotation, the differential pressures through the sealing element 210 and other parameters to calibrate the state of the sealing element 210 and estimate and / or predict the remaining life of the sealing element 210. The estimated life of the sealing element 210 can be compared to a maximum life for the sealing element 210 to determine whether the sealing element
    [26] [26] In other embodiments, the measured vibrations associated with RCD 106 can be used to monitor the condition and performance of the bearings in the bearing assembly 206. The sealing element 210 can be coupled to the bearing assembly 206 using a mandrel ( not shown expressly) so that the sealing element 210 and the mandrel rotate in the bearings in the bearing assembly 206 as a single unit. A measured vibration associated with the mandrel and the sealing element 210 that is equal to or greater than a predetermined threshold that can indicate the condition and / or performance of the bearings in the bearing assembly 206 can be degrading. As such, the drilling operator can adjust various drilling parameters including, but not limited to, rotation speed of drilling column 104, weight on drill and penetration rate in order to optimize the life of the bearings in the 206 bearing assembly .
    [27] [27] The processing system 304 can be communicatively coupled to the display 306 which is part of the control system 300, such that the information processed by the processing system 304 (for example, deformation, pressure, temperature, fluid level, position, material loss and vibration, etc.) can be transmitted to the operators of a drilling system (for example, drilling system 100, as shown in FIGURE 1). The printer 308 and associated prints 308 can also be used to report wear on the RCD 106. Outputs 310 can be communicated to various components associated with the operation of the associated drilling system, to various remote locations to monitor and / or control the performance of the drilling system, or for users who simulate drilling a well hole.
    [28] [28] Modifications, additions or omissions can be made to FIGURE 3, without departing from the scope of the present disclosure. For example, the number of sensors 212 and the drilling conditions measured by sensors 212 may vary depending on the drilling application.
    [29] [29] FIGURE 4 illustrates a flow chart of an example method for monitoring a component condition on a rotary control device during drilling operations in accordance with some of the modalities of the present disclosure. The method is described as being carried out by the sensors 212 described with respect to FIGURE 2 and by the processing system 304 described with respect to FIGURE 3, however, any other suitable system, apparatus or device can be used. Generally, sensors 212 can be incorporated into the sealing element 210 (as illustrated in FIGURE 2) of RCD 106 to measure various drilling conditions during drilling operations. Drilling conditions can include, but are not limited to, deformation, pressure, temperature, fluid level, position, material loss and vibration. The measured values for the various drilling conditions can be used by the processing system 304 to make a determination of the condition of the sealing element 210 and other associated components of RCD 106, including the condition of the bearings in the bearing assembly 206. If the processing system 304 determines that the sealing element 210 and / or the bearings in the bearing assembly 206 are worn, drilling operations can be interrupted so that the sealing element 210 and / or the bearings can be replaced. On the other hand, if the processing system 304 determines that there is no wear or the wear is minimal, the drilling operations can thus continue, avoiding downtime of the drilling probe if the sealing element 210 and / or the bearings of the bearing assembly 206 do not need to be replaced.
    [30] [30] Method 400 can start and in step 402, sensors 212 can measure one or more drilling conditions during drilling operations. Drilling conditions can include, but are not limited to, deformation, pressure, temperature, fluid level, position, material loss and vibration. As described above, these drilling conditions can be used to determine a condition (e.g., quantity and / or wear rate) associated with the sealing element 210 and / or the bearings in the bearing assembly 206.
    [31] [31] In step 404, sensors 212 can report detected drilling conditions to processing system 304 that is configured to receive measurements from sensors 212 during drilling operations. In some embodiments, data representing drilling conditions can be communicated from sensors 212 to input device 302 using transmitters / receivers at various locations in a drilling system (for example, drilling system 100, as shown in FIGURE 1) . Locations may include, but are not limited to, (i) body 204, bearing assembly 206, mooring and upper separator of RCD 106, (ii) hydraulic power unit (HPU), (iii) work platform, console control unit and the drill floor of the drilling unit, such as the drilling unit 102 of FIGURE 1, and (iv) near the wellhead. In other embodiments, data from sensors 212 can be communicated over wires, such as electrical wires or fiber optics. In additional modalities, the communication of the drilling conditions of the sensors 212 can be wireless. For example, the signals that carry the drilling conditions can be acoustic, electromagnetic or optical. Measurements can be communicated by sensors 212 either continuously or based on a predetermined time interval.
    [32] [32] In step 406, processing system 304 can determine whether sealing element 210 and / or bearings in bearing assembly 206 should be replaced based on one or more of the detected drilling conditions. In one embodiment, the processing system 304 can compare the detected drilling conditions with a predetermined threshold. If the detected drilling condition is above or below the predetermined threshold, depending on the particular drilling condition, processing system 304 can determine that the sealing element 210 and / or the bearings in the bearing assembly 206 must be replaced. The comparison of the predetermined threshold can be based on a single measurement of the particular drilling condition or on a change (either increase or decrease) in the drilling condition over time. In addition, processing system 304 can make a determination as to whether sealing element 210 and / or bearings in bearing assembly 206 should be replaced based on a drilling condition or a combination of various drilling conditions. In other embodiments, the detected drilling conditions can be used to calculate the estimated life of the sealing element 210 and / or the bearings of the bearing assembly 206 during drilling operations. The estimated service life of each component can be used to determine whether sealing element 210 and / or bearings in bearing assembly 206 should be replaced. For example, processing system 304 may determine that that sealing element 210 and / or the bearings in the bearing assembly 206 are wearing out at a high rate and should be replaced if the estimated service life is less than the maximum lifetime determined under laboratory conditions. In contrast, an estimated life that is longer than the maximum life span may indicate that the sealing element 210 and / or the bearings in the bearing assembly 206 are wearing out at a decreased rate and that drilling operations may continue. When calculating component life, a failure in sealing element 210 and / or bearing assembly 206 during drilling operations can be prevented and costly downtime due to premature replacement of sealing element 210 and / or bearings in bearing assembly 206 when none is worn can be avoided.
    [33] [33] If processing system 304 determines that oThe sealing element 210 and / or the bearings in the bearing assembly 206 are to be replaced, the processing system 304 can issue an alarm indicating that the sealing element 210 and / or the bearings in bearing assembly 206 are worn in step 408. The alarm can be an audible and / or visual signal to the drilling system operator and can be displayed on display 306. Upon receiving the alarm, the drilling operator can stop the drilling operations in step 410 and the sealing element 210 and / or the bearings in the bearing assembly 206 can be replaced in step 412.
    [34] [34] If processing system 304 determines that oThe sealing element 210 and / or bearings do not need to be replaced, processing system 304 can determine whether any of the drilling parameters should be adjusted based on the drilling conditions in the step 414. For example, processing system 304 can make the determination based on one or more drilling conditions being either above or below a predetermined threshold at a given time or a change in drilling conditions over time. In addition, processing system 304 can calculate the estimated life of the sealing element 210 and / or the bearings in the bearing assembly 206 during drilling operations. If processing system 304 determines that sealing element 210 and / or bearings in bearing assembly 206 will reach its useful life before drilling operations are complete, processing system 304 may determine adjustments to certain drilling parameters a in order to extend the life of the sealing element 210 or the bearings in the bearing assembly 206. If processing system 304 determines that no drilling parameters should be adjusted, drilling operations can continue in step 416 and method 400 can return to step 402 to continue measuring drilling conditions.
    [35] [35] If processing system 304 determines that a drilling parameter must be set, processing system 304 can communicate a suggested setting to the drilling operator via display 306 in step 418. In one embodiment, sensors 212 can provide a vibration measurement associated with RCD 106. The amount of vibration can be used to indicate or estimate the life of the sealing element 210 and / or the bearings in the bearing assembly 206 under any given drilling conditions. If the vibration is above a predetermined threshold, the processing system 304 can generate an alarm and or suggest an adjustment for the drilling operator via display 306 and / or automatically adjust the parameter. For example, the rotation speed of the drilling column 104, the weight on the drill bit, the penetration rate, the separation speed and / or the maneuvering speed can be adjusted in order to reduce vibrations and prolong the life of the bearings in the assembly of bearing 206 and / or sealing element 210. In step 410, the operator can make the adjustment and / or the processing system 304 can automatically adjust the drilling parameters.
    [36] [36] Modifications, additions or omissions can be made to method 400 without departing from the scope of the present disclosure. For example, the order of the steps can be performed in a different way than described and some steps can be performed at the same time. In addition, each individual step may include additional steps without departing from the scope of the present disclosure.
    [37] [37] Although the present disclosure and its advantages have been described in detail, it should be understood that various changes, substitutions and changes can be made here without departing from the spirit and scope of the disclosure, as defined by the following claims.
    权利要求:
    Claims (35)
    [1]
    1. (Original) Drilling system, characterized by the fact that it comprises: a drilling column; a rotary control device (RCD) associated with the drill string, the RCD including a sealing element composed of an elastomeric material; a sensor incorporated in the sealing element, The sensor configured to detect a drilling condition associated with the RCD during a drilling operation; and a control system configured to determine wear of the sealing element based on the drilling condition.
    [2]
    2. (Original) Drilling system, according to claim 1, characterized by the fact that the drilling condition is selected from the group consisting of deformation, pressure, temperature, fluid level, position, material loss and vibration.
    [3]
    3. (Original) Perforation system, according to claim 1, characterized by the fact that the sensor is selected from the group consisting of a nanosensor, an optical fiber and a polymer fiber.
    [4]
    4, (Original) Perforation system, according to claim 1, characterized by the fact that the control system is configured to determine wear of the sealing element by comparing the perforation condition with a predetermined threshold.
    [5]
    5. (Original) Drilling system, according to claim 1, characterized by the fact that the control system is still configured to: calculate an estimated life time of the sealing element based on the drilling condition; compare the estimated lifetime with a maximum lifetime for the sealing element; and determine that the sealing element should be replaced if the estimated lifetime is less than the maximum lifetime.
    [6]
    6. (original) Drilling system, according to claim 1, characterized by the fact that the RCD still comprises: a bearing assembly including a plurality of bearings; a mandrel coupled to the bearing assembly; and the sealing element coupled to the mandrel, the sensor still configured to determine bearing wear on the bearing assembly based on the detected drilling condition.
    [7]
    7. (Currently Amended) Drilling system, according to claim 6, characterized by the fact that the control system is further configured to: determine the wear of the bearings in the bearing assembly by comparing the drilling condition with a predetermined threshold; and determining an adjustment of a drilling parameter based on the wear of the bearings in the bearing assembly.
    [8]
    8. (Original) Drilling system, according to claim 6, characterized by the fact that the control system is still configured to: calculate an estimated life of the bearings in the bearing assembly based on the drilling condition; compare the estimated lifetime with a maximum lifetime for the bearings in the bearing assembly; and determine that the bearings in the bearing assembly should be replaced if the estimated life span is less than the maximum life span.
    [9]
    9. (Canceled)
    [10]
    10. (Canceled)
    [11]
    11. (Canceled)
    [12]
    12. (Original) Rotary control device (RCD) configured to be used in a drilling system, characterized by the fact that it comprises: a sealing element composed of an elastomeric material; and a sensor incorporated in the sealing element, The sensor configured to: detect a drilling condition associated with the RCD during a drilling operation; and communicating the drilling condition to a control system configured to determine wear of the sealing element based on the drilling condition.
    [13]
    13. (Original) Rotary control device, according to claim 12, characterized by the fact that the drilling condition is selected from the group consisting of deformation, pressure, temperature, fluid level, position, material loss and vibration.
    [14]
    14. (Original) Rotating control device, according to claim 12, characterized by the fact that the sensor is selected from the group consisting of a nanosensor, an optical fiber and a polymer fiber.
    [15]
    15. (Original) Rotating control device, according to claim 12, characterized by the fact that it still comprises: a bearing assembly including a plurality of bearings; a mandrel coupled to the bearing assembly; and the sealing element coupled to the mandrel, the sensor still configured to determine bearing wear on the bearing assembly based on the detected drilling condition.
    [16]
    16. (Canceled)
    [17]
    17. (Canceled)
    [18]
    18. (Original) Rotary control device, according to claim 12, characterized by the fact that the sensor is still configured to continuously detect the drilling condition.
    [19]
    19. (Original) Rotating control device, according to claim 12, characterized by the fact that the sensor is further configured to detect the drilling condition within a predetermined interval.
    [20]
    20. (Original) Method for determining a component's condition in a rotary control device for use in a drilling system, characterized by the fact that it comprises: receiving, in a control system, a drilling condition detected during a drilling operation by a sensor incorporated in a sealing element of a rotary control device (RCD); and determining the wear of the sealing element based on the perforation condition.
    [21]
    21. (Original) Method, according to claim 20, characterized by the fact that the drilling condition is selected from the group consisting of deformation, pressure, temperature, fluid level, position, material loss and vibration.
    [22]
    22. (Original) Method, according to claim 20, characterized by the fact that the determination of the wear of the sealing element comprises comparing the perforation condition with a predetermined threshold.
    [23]
    23. (Original) Method, according to claim 20, characterized by the fact that it further comprises: calculating an estimated lifetime of the sealing element based on the drilling condition; compare the estimated lifetime with a maximum lifetime for the sealing element; and determine that the sealing element should be replaced if the estimated lifetime is less than the maximum lifetime.
    [24]
    24, (Original) Method, according to claim 20, characterized by the fact that the RCD still comprises: a bearing assembly including a plurality of bearings; a mandrel coupled to the bearing assembly; and the sealing element coupled to the mandrel, the sensor still configured to determine bearing wear on the bearing assembly based on the detected drilling condition.
    [25]
    25. (Currently Amended) Method, according to claim 24, characterized by the fact that it further comprises: comparing the drilling condition with a predetermined threshold to determine the wear of the bearings in the bearing assembly; and determining an adjustment of a drilling parameter based on the wear of the bearings in the bearing assembly.
    [26]
    26. (Original) Method, according to claim 24, characterized by the fact that it also comprises: calculating an estimated life time of the bearings in the bearing assembly based on the drilling condition; compare the estimated lifetime with a maximum lifetime for the bearings in the bearing assembly; and determine that the bearings in the bearing assembly should be replaced if the estimated life span is less than the maximum life span.
    [27]
    27. (Canceled)
    [28]
    28. (Original) System for determining a component's condition in a rotary control device for use in a drilling system, characterized by the fact that it comprises: a processor; a computer-readable memory communicatively coupled to the processor; and processing instructions encoded in computer-readable memory, processing instructions, when executed by the processor, operable to perform operations comprising: receiving, in a control system, a drilling condition detected during a drilling operation by a sensor embedded in an element sealing a rotary control device (RCD); and determining the wear of the sealing element based on the perforation condition.
    [29]
    29. (Original) System, according to claim 28, characterized by the fact that the drilling condition is selected from the group consisting of deformation, pressure, temperature, fluid level, position, material loss and vibration.
    [30]
    30. (Original) System, according to claim 28, characterized by the fact that the determination of the wear of the sealing element comprises comparing the perforation condition with a predetermined threshold.
    [31]
    31. (Original) System according to claim 28, characterized by the fact that the processing instructions are still operable to perform operations comprising:
    calculate an estimated life time of the sealing element based on the drilling condition; compare the estimated lifetime with a maximum lifetime for the sealing element; and determine that the sealing element should be replaced if the estimated lifetime is less than the maximum lifetime.
    [32]
    32. (Original) System, according to claim 28, characterized by the fact that the RCD still comprises: a bearing assembly including a plurality of bearings; a mandrel coupled to the bearing assembly; and the sealing element coupled to the mandrel, the sensor still configured to determine bearing wear on the bearing assembly based on the detected drilling condition.
    [33]
    33. (Currently Amended) System according to claim 32, characterized by the fact that the processing instructions are still operable to perform operations comprising: comparing the drilling condition with a predetermined threshold to determine the wear of the bearings in the set of bearing; and determining an adjustment of a drilling parameter based on the wear of the bearings in the bearing assembly.
    [34]
    34. (Original) System according to claim 32 characterized by the fact that the processing instructions are still operable to perform operations comprising: calculating an estimated life of the bearings in the bearing assembly based on the drilling condition; compare the estimated lifetime with a maximum lifetime for the bearings in the bearing assembly; and determine that the bearings in the bearing assembly should be replaced if the estimated life span is less than the maximum life span.
    [35]
    35. (Canceled)
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    同族专利:
    公开号 | 公开日
    RU2015120611A|2017-02-03|
    WO2014105077A3|2015-06-18|
    AU2012397805A1|2015-06-11|
    CA2893128A1|2014-07-03|
    EP2912262A2|2015-09-02|
    MX2015006916A|2015-11-09|
    WO2014105077A2|2014-07-03|
    US10081985B2|2018-09-25|
    US20150337599A1|2015-11-26|
    EP2912262A4|2016-07-13|
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    法律状态:
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2020-11-17| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2021-03-02| B11B| Dismissal acc. art. 36, par 1 of ipl - no reply within 90 days to fullfil the necessary requirements|
    2021-12-07| B350| Update of information on the portal [chapter 15.35 patent gazette]|
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    PCT/US2012/072268|WO2014105077A2|2012-12-31|2012-12-31|Monitoring a condition of a component in a rotating control device of a drilling system using embedded sensors|
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