• 专利附录
  • 专利说明
  • 权利要求
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    • 专利摘要:
    SYSTEM FOR SEATING A SUBMARINE WELL HEAD COMPONENT AND METHOD FOR SEATING A SUBMARINE WELL HEAD DEVICE The present invention relates, in general, to the detection of the torque and weight applied to a drilling column and, in particular, to the detection of the torque and weight applied to the drilling column at mud flue and sub-mud flue levels. the system for laying a subsea wellhead component (35) comprises a laying tool (31) is adapted to transport and adjust the component; a dynamometer rod (29) which has a bi-directional weight and torque sensor and is adapted to be coupled in line with the seating column, and additionally coupled to the seating tool (31), so that the dynamometer rod (29) measures a weight and torque applied to the seating tool (31) and produce a signal in response; a receiving rod adapted to be coupled in line with the settlement column above sea level; being that the dynamometer rod is communicatively coupled to the receiving rod, so that the receiving rod can receive the signal from the dynamometer rod (29); a display to present the signal in real time to the operator.
    公开号:BR102012004766B1
    申请号:R102012004766-7
    申请日:2012-03-02
    公开日:2020-11-03
    发明作者:Francisco Kazuo Kobata；Lucas Antonio Perrucci；Pedro Paulo Alfano；Rafael Romeiro Aymone
    申请人:Vetco Gray, Inc；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    [001] The present invention relates, in general, to the detection of the torque and weight applied to a drilling column and, in particular, to the detection of the torque and weight applied to the drilling column in mud flue and flue levels. sub-mud. BACKGROUND OF THE INVENTION
    [002] In subsea drilling operations, a drilling vessel usually floats over an area that will be drilled. The drilling vessel then sits on a drilling riser that extends from the surface drilling vessel to a wellhead located on the seabed. The drilling riser serves as the lifeline between the vessel and the wellhead, since most drilling operations are performed using the drilling riser. Since devices are required for the well, such as cladding hangers, bridge hangers, seals, wear bushings and the like, these pass from the vessel's surface in a drill string through the riser, to the wellhead and to the inside of the well hole. Weight and rotation are used to place and operate these devices. Because of this, it is important to know with some specificity the weight and torque applied to the device in the subsea environment to know that the device has reached the appropriate position in the well bore and has been properly activated. This is typically accomplished by measuring the torque and weight applied to the drilling vessel.
    [003] Due to the fact that drilling vessels float over the underwater wellhead, they are subjected to the effects of ocean currents and winds. Ocean currents and winds drive drilling vessels so that they do not remain completely stationary over the wellhead, despite attempts to anchor them to the seabed. Also, the riser itself is subjected to movement due to ocean currents. Because of this, the riser does not truly remain vertical between the wellhead and the drilling vessel. Instead, the riser "curves" in response to the vessel's position in relation to the wellhead and to the effects of the current on the non-anchored riser sections that extend between the anchored ends on the drilling vessel and the wellhead. As locations in deeper waters are explored, the problem is exacerbated.
    [004] As the riser curves, the drill string that passes through the riser will come into contact with the riser, instead of remaining suspended between the riser walls. In locations where the drill string comes into contact with the riser wall, the drill string becomes anchored and transmits some of the operating weight and torque applied by the drill rig to the drill string from the drill string to the riser . In this way, the actual torque and weight applied to the device at the borehole are less than the total torque and weight applied to the drilling vessel. Due to the fact that the devices depend on the appropriate weight and torque to seat, adjust and test in the appropriate position in the well bore, the loss of torque and weight due to the anchoring of the drill string against the riser may mean that operators on the drilling devices are not testing, adjusting or properly fitting the devices, due to the fact that they base their actions on torque and weight measurements taken on the drilling vessel. To ensure that the proper torque and weight are applied to seat, adjust and test the devices, torque and weight measurements applied to the device's location are required.
    [005] A prior art method for detecting that the appropriate weight and torque has been applied to set down a downhole consumable involves the use of specially furrowed linings in the downhole consumable settlement locations. The proximity sensors are then incorporated into the consumable or, alternatively, in a separate tool aligned with the consumable. Proximity sensors are disarmed when the grooves in the special coating are close to the sensors. The proximity sensors then generate an acoustic signal that is received on the platform and interpreted as a tool seating. Unfortunately, these devices require the use of special tools and special coatings in order to properly generate an adjustment / seating signal. Furthermore, the devices are unable to provide information about the weight and torque applied to the consumable material, which can indicate whether the probe and well are out of position with each other or that the drilling column is anchored.
    [006] Another prior art method for detecting weight and torque at a downhole location involves using suspended strain gauge sensors to measure and record weight and torque at downhole locations. However, these sensors are not used to determine what is happening in real time, but instead to determine friction losses during drilling, before adjusting any downhole consumables. The data and calculations of these devices are studied and used to conduct drilling operations at similar locations and types of training. These do not provide real-time feedback to an operator during the laying, adjustment and testing of wellhead consumables. Therefore, there is a need for a method and apparatus to detect the weight and torque in a mud flue during the laying, adjustment and testing of subsea wellhead devices. DESCRIPTION OF THE INVENTION
    [007] These and other problems are usually solved or circumvented and the technical advantages are generally achieved by the preferred embodiments of the present invention that provide a device for measuring weight and torque in downhole locations in real time and a method for using the same .
    [008] In accordance with an embodiment of the present invention, a system for measuring torque and weight applied by a drilling rig to a drilling column in a well-bottomed underwater settlement tool, comprises a dynamometer rod, a receiver rod and a display. The dynamometer rod has a bi-directional weight and torque sensor coupled in line with the drilling column. The dynamometer rod is additionally coupled to the seating tool, so that the dynamometer rod measures a torque and weight applied to the seating tool and produces a response signal. The dynamometer rod is communicatively coupled to a receiving rod, such that the receiving rod can receive the signal from the dynamometer rod. The receiving rod is, in turn, coupled in line with the drilling column on a rotary table of the drilling rig, and additionally connected communicatively to a display located next to a drill rig operator. The communicative coupling between the receiving rod and the display allows the receiving rod to transmit the signal to the display. The display, in turn, shows the signal in real time to the operator.
    [009] In accordance with another embodiment of the present invention, a system for measuring torque and weight applied by a drilling rig to a drilling column in a well-bottomed subsea tool, comprises a dynamometer rod, a transmitter of signal, a signal receiver and a display. The dynamometer rod has a bidirectional load cell coupled in line with the drilling column and additionally coupled to the seating tool. The signal transmitter is coupled to the dynamometer rod and the bidirectional load cell. The signal transmitter is configured to receive a plurality of signals from the bidirectional load cell and transmit these signals to the signal receiver. The signal receiver is communicatively coupled to the display, and the display is configured to present the signal in a manner understood by an operator in real time.
    [010] In accordance with yet another embodiment of the present invention, a method for detecting weight and torque in a mud flue during the laying of subsea wellhead consumables applied by a drilling rig to a drilling column in a deep-sea subsea settlement tool comprises the following steps. First, the method provides a weight and torque detection system and couples it in line with the drilling column and the laying tool. Then, the method introduces the detection system in a downward way in an underwater riser and inside the mud flue of a well hole. The method then operates the seating tool and generates a signal in a bidirectional load cell of the weight and torque detection system in response to the seating tool's operation. The method then transmits the signal from a bidirectional load cell from the detection system to a display on the drill rig, and communicates the signal to a drill rig operator.
    [011] An advantage of a preferred embodiment is that it provides a measurement of the torque and weight applied at a device location in the underwater well bore in real time. This allows operators of a drilling vessel to be more confident that the device has been properly seated and fitted into the well bore. Also, through the comparison with measurements of torque and weight applied to the surface, operators will have an indication that the drilling column was anchored to the submarine riser. BRIEF DESCRIPTION OF THE DRAWINGS
    [012] Since the manner in which the characteristics, advantages and objectives of the invention, as well as others that will become apparent, are achieved and can be understood in greater detail, a more particular description of the invention briefly summarized above can be taken as a reference for its achievements which are illustrated in the attached drawings which form a part of this specification. It should be noted, however, that the drawings illustrate only one preferred embodiment of the invention and, therefore, should not be considered as limiting its scope, since the invention can admit other equally effective realizations: Figure 1 is a schematic representation of a riser that extends between a wellhead assembly and a floating platform; Figure 2 is a schematic representation of a drilling tool that employs an embodiment of the present invention; Figure 3 is a schematic representation of an exemplary measurement tool used in Figure 2; Figures 4A and 5B are schematic representations of weight and torque sensors used by the exemplary measurement tool in Figure 3; Figure 6 is a schematic representation of an alternative measurement tool; Figure 7 is a schematic representation of a receiving tool used in an embodiment of the present invention; Figure 8 is a schematic representation of the measurement tool, the receiving tool and a display area communicatively coupled in an embodiment of the present invention; Figure 9 is a schematic representation of an alternative embodiment of the present invention; Figures 10 and 12 are schematic representations of a coating hanger laying tool in operational stages of laying, adjusting and / or testing a subsea wellhead material. DESCRIPTION OF ACCOMPLISHMENTS OF THE INVENTION
    [013] The present invention will now be described more fully hereinafter with reference to the accompanying drawings illustrating the embodiments of the invention. This invention can, however, be incorporated in many different forms and should not be construed as limited to the embodiments illustrated herein. Preferably, these achievements are provided so that this disclosure is thorough and complete and fully transmits the scope of the invention to a person skilled in the art. Similar numbers refer to similar elements throughout the document, and the main annotation, if used, indicates similar elements in alternative embodiments.
    [014] In the following discussion, numerous specific details are presented to provide a complete understanding of the present invention. However, it will be apparent to one skilled in the art that the present invention can be practiced without such specific details. In addition, for the most part, details regarding the drilling rig operation, riser assembly and disassembly, operation and use of wellhead and similar consumables have been omitted as such details are not considered necessary to obtain a complete understanding of the present invention and are considered to be within the abilities of the person of a person skilled in the art.
    [015] Referring to Figure 1, there is shown a floating drilling rig 11 connected to a wellhead assembly 13 on a seabed by a riser 15. A column 17, such as a coating column or auxiliary coating column , extends from the wellhead assembly 13 to a subsurface well hole bottom (not shown). The riser 15 allows the drill pipe 19 to be positioned from the floating platform 11 in the wellhead assembly 13 and into the column 17 below a mud flue 14. The drill column 19 receives rotational torque and a downward force or weight from drilling devices located on the floating platform 11. During rigid member assembly, riser 15 does not remain completely rigid as it traverses the distance between the floating platform 11 and the wellhead assembly 13. The riser 15 is made up of joints, each of which can allow some movement from a substantially vertical movement. The combined effect of light movement of each joint will cause the riser 15 to "tilt" in response to the vertical movement of the floating platform 11 due to swelling of the surface 23, lateral movement caused by an underwater current 21, and lateral movement of the floating platform 11 in response to a wind 25. As shown, underwater current 21, swelling 23 and wind 25 moved the floating platform 11, so that the riser 15 remained in the curved position shown in Figure 1.
    [016] Drill column 19 does not "tilt" in response to environmental conditions. The drill column 19 remains substantially rigid as it passes through the riser 15 of the floating platform 11 to the wellhead assembly 13 and then into the column 17. Consequently, an outer diameter of the drill column 19 will enter in contact with an internal diameter surface of the riser 15 as shown in contact locations 27. In these locations, a portion of the actual rotational torque and weight applied to the drill column 19 on the floating platform 11 is transferred from the drill column 19 to the riser 15, causing the actual torque and weight applied to downhole tools to be less than those applied to the surface.
    [017] As shown in Figure 2, to measure the actual rotational torque and weight applied in or below the mud flue 14, a dynamometer rod 29 is coupled in an aligned way between a laying tool 31 and the drill column 19 during the adjustment of an underwater wellhead equipment, such as a coating hanger 32, by the laying tool 31. The laying tool 31 is a conventional tool used to seat and operate the subsea wellhead equipment such as coating hangers, piping, fences, wellhead housings, trees, etc. The seating tool 31 is seated on a drilling column 19 in a position inside the wellhead assembly 13 as a safety valve (BOP) 33 or, also below the column 17, as in the wellhead 35 or even, additionally, in the pit. A dynamometer rod 29 contains operational elements that measure rotational torque and weight applied to the seating tool 31. These measurements can be communicated to the drilling rig 11 in any suitable mode or, optionally, stored on the dynamometer rod 29 and retrieved in a future date. In the illustrated embodiment, measurements are communicated to the drilling platform 11 in real time, so that an operator on the platform 11 can respond accordingly.
    [018] Referring now to Figure 3, a detailed view of the dynamometer rod 29 is shown. A dynamometer rod 29 can include a tubular body 37, an acoustic transmitter 39, a battery 41, a plurality of extensometers 43, elastomeric seals 45, a protective sleeve 47, a retaining nut 49, a wrench 51 and an adjusting screw 53. The tubular body 37 defines a hole 36 that has a geometry axis 38 to allow drilling fluids or hydrocarbons to pass through, depending on the operation particular under which the well is being subjected. The tubular body 37 has an upper end 55 configured to couple with the drill column 19 (Figure 2). One skilled in the art will understand that the coupling could be a threaded connection, a clamping connection or any other suitable drill string coupling. Similarly, the tubular body 37 (Figure 3) has a lower end 57 configured to engage the seating tool 31 (Figure 2). One skilled in the art will understand that the coupling could be a threaded connection, a clamping connection or any other suitable drill string coupling.
    [019] A lower body recess 59 is formed in a lower portion of tubular body 57 with a size and shape such that the protective sleeve 47 can slide over the tubular body 37 in the lower body recess 59 circumscribing the tubular body 37. In illustrated embodiment, a protective sleeve 47 outer diameter surface will be flush with an outer diameter surface of the tubular body 37 when the protective sleeve 47 circumscribes the tubular body 37 after assembly. The tubular body 37 further defines a transmitting recess 61 and a battery recess 63. Both the transmitting recess 61 and the battery recess 63 extend from an outer diameter surface of the lower body recess 57 inwardly towards the orifice 36. The transmitting recess 61 has a size and shape such that the acoustic transmitter 39 can fit into the transmitting recess 61, substantially filling the transmitting recess 61, while allowing the protective sleeve 47 to circumscribe the tubular body 37 in the lower body recess 59. similarly, the battery recess 63 is of a size and shape such that the battery 41 can fit into the battery recess 63, substantially filling the battery recess 63, while allowing the protective sleeve 47 to circumscribe the tubular body 37 in the body recess. lower 59.
    [020] Seal 45 can be formed of elastomer and comprises an O-ring as shown. The seal 45 will pass through the lower body recess 59, and, afterwards, the protective sleeve 47 circumscribes the lower body recess 59, the sealing of an annular space between the protective sleeve 47 and the tubular body 37. During assembly, after protective sleeve 47 to slide over the lower body recess 59, the retaining nut 49 can be threaded onto the tubular body 37 by means of a compatible thread 65 formed on the outer diameter surface of the tubular body 37, so that the retaining nut 49 is borderline a and hold protective sleeve 47 in place. In the illustrated embodiment, retainer nut 49 is additionally secured by wrench 51 fitted in a slot in retainer nut 49 and held in place with adjusting screw 53.
    [021] An annular caliber recess 67 is formed on the lower body recess surface 59 axially below the transmitter recess 61 and battery recess 63 and axially above the thread 65. The caliber recess 67 extends from the body recess surface lower 59 radially inward towards orifice 36. The recess of caliber 67 is of sufficient depth that the plurality of gauges 43 can be placed in the recess of caliber 43, while allowing protective sleeve 47 to slide over gauges 43 without interfering in your operation. In addition, the lower body recess surface 59 can be contoured between the transmitter, battery and caliber recesses 61, 63, 67 to allow a communicative coupling to be made between the battery 41, the acoustic transmitter 39 and extensometers 43. exemplary embodiment, the tubular body 37 is made of SAE 4340 steel, cooled down and tempered in 42HRC. Alternative embodiments can use any suitable material that has a high yield stress and low hysteresis, such as aluminum 6061 or similar.
    [022] Battery 41 comprises an electrical battery storage potential that can be transmitted and used by a device that needs electrical current to operate. The acoustic transmitter 39 can be such a device. The acoustic transmitter 39 may include a controller configured to receive battery electrical potential 41 and supply a voltage to the extensometers 43. The acoustic transmitter 39 is configured to supply the extensometers 43 with a stable voltage and receive a variable voltage in response. The acoustic transmitter 39 can receive a voltage from the extensometers 43 and communicate that voltage received from the extensometers 43 to the devices at the top of the hole as an acoustic signal. Before communicating the signal at the top of the hole, the acoustic transmitter 39 can pass the signal through an amplification circuit optionally included in the acoustic transmitter 39. In operation, the battery 41 is electrically coupled to the acoustic transmitter 39, such that the transmitter 39 can receive energy from battery 41. In turn, the acoustic transmitter 39 is electrically coupled to extensometers 43, such that the acoustic transmitter 39 can supply a voltage to the extensometers 43 and receive a voltage from the extensometers 43 in response to the voltage supplied. In the exemplary embodiment, when the seating tool 31 operates through a load applied to the platform 11, the extensometers 43 will operate as described below to supply a response voltage that is read by the acoustic transmitter 39 and then communicated at the top of the hole by the acoustic transmitter 39.
    [023] Referring now to Figures 4A to 5B, the plurality of extensometers 43 is arranged to form a two-channel two-way load cell. In the exemplary embodiment, one channel is arranged to measure the weight, and a second channel is arranged to measure the torque. The plurality of extensometers can include eight extensometers arranged to form two separated Wheatston bridges. The first, as illustrated in Figure 4A, can be on the first channel and be arranged to include four strain gauges 69, 71, 73 and 75 connected to the surface of tubular body 37 in a 67 caliber recess. In the exemplary embodiment, the arrangement of the illustrated extensometer in Figure 4B is used to measure the weight. Two extensometers 69, 73 will be aligned parallel to the geometric axis 38, and two extensometers 71, 75 will be aligned perpendicular to the geometric axis 38. The extensometers 71 and 75 will be on diametric sides of the tubular body 37. Similarly, the extensometers 69 and 73 will be on diametric sides of the tubular body 37.
    [024] As shown in Figure 4B, the extensometers 69, 71, 73 and 75 will be connected communicatively as follows. The extensometer 69 can be attached to a first end up to a first end of the extensometer 71. A second end of the extensometer 69 can be attached to a first end of the extensometer 75. A second end of the extensometer 71 can be attached to a first end of the extensometer 73. A second end of the extensometer 73 can be coupled to a second end of the extensometer 75. A voltage is applied to input nodes 70 connecting the extensometers 69 and 71 and 73 and 75. A corresponding output voltage can be read at nodes of output 72, connecting extensometers 69 and 75, and 71, 73. The acoustic transmitter 39 communicates with input nodes 70 to connect the extensometers 69 and 71, and 73 and 75, to apply a known voltage input. The acoustic transmitter 39 is, in turn, coupled to output nodes 72 in strain gauges 69 and 75, and 71 and 73 from which an output voltage is read and transmitted.
    [025] The second Wheatstone bridge, as illustrated in Figures 5A and 5B, can be on the second channel and be arranged to include four extensometers 77, 79, 81, and 83 connected to the surface of the tubular body 37 in the 67-gauge recess. In the example, the extensometer arrangement shown in Figure 5A is used to measure the torque. Two strain gauges 77, 81 will be aligned at a negative 45 degree angle to a geometric axis perpendicular to the geometry axis 38, and two strain gauges 79, 83 will be aligned at a positive 45 degree angle to a perpendicular geometric axis. to the geometric axis 38. Extensometers 77 and 81 will be on diametric sides of tubular body 37. Similarly, extensometers 79 and 83 will be on diametric sides of tubular body 37.
    [026] As shown in Figure 5B, strain gauges 77, 79, 81, and 83 will be communicatively coupled as follows. The extensometer 77 can couple a first end to a first end of the extensometer 79. A second end of the extensometer 77 can couple to a first end of the extensometer 83. A second end of the extensometer 79 can couple to a first end of the extensometer 81. A second end of an extensometer 81 can couple with a second end of an extensometer 83. A voltage is applied to input nodes 78 that connect extensometers 77 and 79, and 81 and 83. A corresponding output voltage can be read at output nodes 80 that connect extensometers 77 and 83, and 79, 81. The acoustic transmitter 39 communicates with input nodes 78 that connect the extensometers 77 and 79, and 81 and 83. A known voltage is applied to these nodes by the acoustic transmitter 39 The acoustic transmitter 39 is, in turn, coupled to output nodes 80 in strain gauges 77 and 83, and 79 and 81 from which an output voltage is read and transmitted. The acoustic transmitter 39 is powered by an electrical coupling to the battery 41. Prior to placement in the drill column 19, the acoustic transmitter 39 is powered to begin applying voltage to and reading the voltage from the two Wheatstone bridges of the example embodiment. One skilled in the art will understand that additional Wheatstone bridge arrangements of extensometer can be used to provide further data adjustments.
    [027] The acoustic transmitter 39 can receive the reading of the output nodes and convert the electrical voltage into an acoustic signal in any suitable mode. The acoustic transmitter 39 can be connected to the tubular body 37, so that the acoustic transmitter 39 can generate an acoustic signal which can then transmit the acoustic signal through the drill pipe 19 to a receiving rod 87 described below with respect to the Figure 7.
    [028] Before positioning the downhole, dynamometer 29 is calibrated as follows. The voltage is applied to extensometers 43 at input nodes 70, 78 described above, and an output voltage is read and written from output nodes 72, 80 as the base output voltage. An external device will then apply a known weight and torque load to dynamometer 29, while the same voltage is applied to extensometers 43 at input nodes 70, 78. A corresponding voltage is read and written from output nodes 72 , 80. The process is repeated to create a data set that reports the load applied to the output voltage produced. From this data set, an equation of the calibration moment is created, which will allow a load applied to the dynamometer to be determined from an output voltage read from the output nodes 72, 80.
    [029] In an alternative embodiment, illustrated in Figure 6, a data recorder 85 can replace the acoustic transmitter 39. The data recorder 85 will be coupled to the plurality of extensometers 43 as described above with respect to the acoustic transmitter 39 in Figures 4A a 5B. However, unlike the acoustic transmitter 39, data recorder 85 will not transmit the signal to the surface. Instead, data logger 85 will store all readings taken on a data storage unit for analysis after removing the dynamometer rod 29 from the well bore.
    [030] Referring now to Figure 7, a detailed view of the receiving rod 87 which is located above sea level and receiving the acoustic signal from the acoustic transmitter 39 is shown. The receiving rod 87 can include a tubular receiver body 97 , an acoustic receiver 89, a battery 90, a radio transmitter 91, receiver elastomeric seals 99, a receiver protective sleeve 101, a receiver retainer nut 103, a receiver key 105 and a receiver adjustment screw 107. The receiver body 97 defines a receiving orifice 95 having a geometrical axis 93 to allow the passage of drilling fluids or hydrocarbons, depending on the particular operation under which the well is currently being subjected. The receiving body 97 has an upper end 109 and a lower end 121 configured to couple with the drill column 19 (Figure 2 and Figure 8). One skilled in the art will understand that the coupling could be a threaded connection, a clamping connection or any other suitable drill string coupling.
    [031] A recess of the receiving body 111 is formed in a lower portion of the receiving body 97 of a size and shape such that the protective protective sleeve 101 can slide over the receiving body 97 in the recess of the receiving body 111 which circumscribes the receiving body 97 in the recess of the receiver body 111 after assembly. In the illustrated embodiment, an outer diameter surface of the receiving protective sleeve 101 will be flush with an outer diameter surface of the receiving body 97 when the protective sleeve 101 circumscribes the receiving body 97. The receiving body 97 further defines a receiving battery recess 113, a receiving recess 115 and a receiving transmitter recess 117 on the reverse side of Figure 7. The receiving battery recess 113, the receiving recess 115 and the receiving transmitter recess 117 extend from an outer diameter surface of the receiving body recess. 111 inwardly towards receiver hole 95. The receiver battery recess 113 is of a size and shape such that the battery 90 can fit into the receiver battery recess 113, substantially filling the receiver battery recess 113, while allowing the sleeve protective receptacle 101 circumscribes the receiving body 97 in the recess of the receiving body 111. Similarly, the receiving recess 115 is of a size and shape such that the acoustic receiver 89 can fit into the receiving recess 115, substantially filling the receiving recess 115, while allowing the protective protective sleeve 101 to circumscribe the receiving body 97 in the receiving body recess 111. Also, the transmitting recessed receiver 117 is of a size and shape such that the radio transmitter 91 can fit into the receiving recess transmitter 117, substantially filling the receiving recess transmitter 117, while allowing the receiving protective sleeve 101 to circumscribe the receiving body 97 in the body recess. receiver 111.
    [032] Receiver seal 99 can be formed of elastomer and comprises an O-ring shape as illustrated. The receiver seal 99 will pass through the receiver body recess 111, and, after the protective receiver sleeve 101 circumscribes the receiver body recess 111, the sealing of an annular space between the protective receiver sleeve 101 and the receiver body 97. During assembly, after the protective receiving sleeve 101 slides over the recess of the receiving body 111, the receiving retaining nut 103 can be threaded onto the receiving body 97 by means of a compatible receiving thread 119 formed on the outer diameter surface of the receiving body 97, such that the nut receiving retainer 103 is boundary to and holding protective protective sleeve 101 in place. In the illustrated embodiment, the receiving retaining nut 103 is additionally secured by the receiving key 105, which is inserted into a slot in the receiving retaining nut 103 and held in place with the adjusting screw receiver. 107. In the exemplary embodiment, the receiver body 97 is formed of SAE 4340 steel, cooled down and tempered in 42HRC. The alternative modalities can use any suitable material that has a high yield stress and low hysteresis, such as aluminum 6061 or similar.
    [033] In the example, the battery 90 is coupled to the acoustic receiver 89 and radio transmitter 91 to supply both with electrical potential. Similar to the acoustic transmitter 39, the receiver 89 can be connected to the receiver body 97, so that the acoustic receiver 89 can receive the acoustic signal generated by the acoustic transmitter 39 through the metal tube of the seat column 19. Alternatively, the The acoustic signal can pass through any suitable medium, such as liquid in the riser 15 or liquid in the seating column 19, provided that the acoustic transmitter 39 and the acoustic receiver 89 are positioned to generate and receive the signal through that medium. If so, the receiving rod 87 will have a detection portion submerged in the liquid in the riser 15 or in the seating column 19. The radio transmitter 91 is above the liquid in order to send an RF signal. The acoustic receiver 89 is, in turn, communicatively coupled with the radio transmitter 91. When the acoustic receiver 89 receives an acoustic signal from the acoustic transmitter 39, the acoustic receiver 89 converts the signal into one that can be received by the radio transmitter 91 and then transmits that signal to radio transmitter 91. Radio transmitter 91 will in turn convert the signal into a radio signal and transmit the signal to a radio receiver 123 (Figure 8) on platform 11 ( Figure 1).
    [034] In the operation as illustrated in Figure 2 and Figure 8, an operator will couple the dynamometer rod 29 to the seating tool 31 and connect the coating hanger 32 with the seating tool 31 as described below. The operator will then seat the drill tool 31, the dynamometer rod 29 and the liner hanger 32 inside the riser 15. The operator assembles the seating column 19 and when the seating tool 31 is close to the head assembly submarine well 13, it connects the receiving rod 87 to the seating column 19 on platform 11. A receiving rod 87 is above sea level. A dynamometer rod 29 is fed before the underwater dynamometer rod 29 is seated. A receiving rod 87 is fed by the operator when the operator wants to know the operating torque on the seating tool 31. In the exemplary embodiment illustrated in Figure 8, the receiving rod 87 will be in the wireless communication range with a radio receiver 123 connected communicatively to a display 125 in an operator's cabin located on floating platform 11, as shown in Figure 1 and Figure 8.
    [035] Torque and weight are applied to the drill column 19 to drive the coating hanger 32 in the following mode. Referring to Figure 10, an embodiment is generally shown for a seating tool 31 that is used to fit a coating hanger. The seating tool 31 is composed of a rod 135. The rod 135 is a tubular member with an axial passage 137 that extends through it. The rod 135 connects its upper end to the dynamometer 29. The dynamometer 29, therefore, engages the seating column 19, as described above. A lower portion of stem 135 has threads 139 on its outer surface.
    [036] The seating tool 31 has an inner body 141 that surrounds the stem 135, as the stem 135 extends axially through the inner body 141. The inner body 141 has an upper body portion 143 and a body portion bottom 145. The lower body portion 145 of inner body 141 is connected to a bearing cover 147. The bearing cover 147 has threads 149 along its inner surface which are engaged with threads 139 on the outer surface of the stem 135. A lower portion 145 of inner body 141 and bearing cover 147 house an engaging element 151. In this particular embodiment, engaging element 151 is a set of tabs having a smooth inner surface and a contoured outer surface. The outer contoured surface is adapted to engage a complementarily contoured surface 153 on the inner surface of a coating hanger 32 when the engaging element 151 is engaged with the coating hanger 32. Although not shown, a coating column is attached to the lower end of the coating hanger 32.
    [037] The lower body portion 145 of the inner body 141 has an internal recess with threads 155 along its inner surface. A meat 157 is positioned between the rod 135 and the inner recess of the inner body 141. The flesh 157 has threads 158 on its outer surface which are engaged with threads 155 on the surface of the inner recess of the lower body portion 145 of the inner body 141 The meat 157 and the stem 135 are connected to each other, so that the meat 157 and the stem 135 rotate in unison, but the meat 157 can move axially in relation to the inner body 141, independent of the stem 135. For example, the meat 157 and the stem 131 can be connected to each other by means of anti-rotation keys.
    [038] An outer body or piston 159 surrounds stem 135 and substantial portions of inner body 141. Piston 159 is connected to stem 135 such that the two rotate and move in unison. An adjustment sleeve 161 is connected to the lower end of the piston 159. The adjustment sleeve 161 carries a sealing ring 163 that is positioned along the lower end portion of the adjustment sleeve 161. The sealing ring 163 will act to seal the liner hanger 32 in a high pressure housing 165 when properly adjusted. While piston 159 is in the upper position, sealing ring 163 is spaced above casing hanger 32.
    [039] With reference to Figure 10, in operation, the seating tool 31 is initially positioned, so that it extends axially through a sheath hanger 32. Piston 159 is in an upper position and the sealing ring of the hanger liner 163 is carried by the adjusting sleeve 161 which is connected to piston 159. The seating tool 31 is lowered into the liner hanger 32 until the outer surface of the inner body 141 and bearing cover 147 of the seating tool 31 engage. sliding with the inner surface of the coating hanger 32.
    [040] Since the laying tool 31 and liner hanger 32 are in bordering contact with each other, stem 135 is rotated in four revolutions. As the stem 135 rotates, a portion of the same unscrews the bearing cover 147 and the stem 135 and the piston 159 move longitudinally downwardly relative to the inner body 141. As the stem 135 is rotated with respect to the body internal 141, the meat 157 rotates in unison and simultaneously detaches from the internal body 141 and moves longitudinally downwards in relation to the internal body 141. A shoulder 164 on the external surface of the meat 157 comes into contact with the engaging element 157, forcing it radially outwards and in contact with the profile 153 on the inner surface of the coating hanger 32, thereby locking the inner body 141 on the coating hanger 32. Once the laying tool 31 and the hanger liners 32 are locked in relation to each other, the laying tool 31 and the liner hanger 32 are lowered from the riser into a high pressure housing 165 until the liner hanger 32 is seated as shown in Figure 10.
    [041] As shown in Figure 11, stem 135 is then rotated in four additional revolutions in the same direction. As the stem 135 is rotated in relation to the inner body 141, the stem 135 completely unscrews from the bearing cover 147, releasing the stem 135 and piston 159 to move more longitudinally downwards with respect to the inner body 141 and the coating hanger 32. During rotation, dynamometer deformation 29 will occur, generating an output voltage at output nodes 72, 80 as described above with respect to Figures 4A and 5B, which is then transmitted as described below.
    [042] With reference to Figure 12, the weight is then applied down the column of the drill pipe (not shown) and subsequently on the dynamometer rod 29, rod 135 and piston 159. As the rod 135 and piston 159 move more longitudinally downwards with respect to the inner body 43, the sealing ring 163 sits between the liner hanger 32 and the high pressure housing 165, engaging radially to the outer surface of the hanger. liner 32 and the inner surface of the high pressure housing 165. This adjusts the liner hanger 32. The weight applied in this process again will deform the dynamometer 29, generating an output voltage at output nodes 72, 80 which is then transmitted to the surface by the dynamometer rod 29 as described below.
    [043] Dynamometer rod 29 will measure the torque and weight applied to the downhole location of dynamometer rod 29 through the plurality of extensometers 43 that operate as described above. The acoustic transmitter 39 will then produce an acoustic signal that represents the difference in voltage produced by the plurality of strain gauges 43 in response to the applied load and the known applied voltage. The acoustic signal passes through the seating column 19, or liquid within or surrounding the seating column 19. The acoustic receiver 89 receives that acoustic signal, converts the acoustic signal into an electrical signal, and then relays the electrical signal to the radio transmitter 91 where the signal is converted to a wireless signal which is then transmitted to radio receiver 123. radio receiver 123 then converts the signal back to an electrical signal and transmits the signal to the display 125 located near the operator.
    [044] The display 125 will then convert the signal indicating the voltage on the extensometers 43 into a signal understood by the operator to report the actual weight and torque applied in the location of the dynamometer rod 29 in the wellhead 13 based on the equation of the calibration moment determined during dynamometer rod calibration 29. From this, the operator will then be able to compare the torque and weight applied to those that his instrumentation told him to apply on platform 11. In this mode, the operator can then, adjust the torque and weight on the surface to achieve the desired torque and weight at the location of the dynamometer rod 29. A person skilled in the art will understand that the conversion of communicative signals can be performed in any suitable mode. Similarly, the calculation of the torque and weight applied to the dynamometer rod 29 based on the response voltage produced by the extensometers 43 can be performed by any of the devices along the signal route or by any additional suitable device in communication with the apparatus .
    [045] In an alternative embodiment illustrated in Figure 9, a second dynamometer rod or rotary table dynamometer 127 can be coupled in line with the drilling column 19 at the level of the rotary table together with a second receiver rod or rotary table receiver 129 The alternative embodiment includes the elements of the embodiments of Figures 1 to 8 described above. The rotary table 127 and rotary table receiver 129 include the components of and will operate as described above with respect to the dynamometer rod 29 and receiver rod 87, respectively. The turntable receiver 129 can communicate the signal received from the turntable dynamometer 127 with a second wireless receiver 133 which can then display the turntable signal on a second display 131. In this mode, the operator can receive a second rotary table reading that will allow the operator to better understand what is happening at the bottom of the well and synchronize the data received for future study.
    [046] Accordingly, the revealed revelations provide numerous advantages. For example, the achievements revealed allow operators to have a better understanding of what is happening at rock bottom. Furthermore, they allow operators to adapt to the loss of torque and weight, communicating in real time the actual torque and weight applied in a downhole location. In this mode, the revealed revelations help operators to ensure that the equipment placed at the bottom of the well is properly adjusted and activated, increasing the likelihood of drilling and successful production in subsea wells. In addition, these provide an indication to the operator that the platform is not aligned with the wellhead, providing the operator with an opportunity to pull the riser to force the vertical alignment of the platform on the wellhead.
    [047] It is understood that the present invention can take many forms and realizations. Accordingly, numerous variations can be made in the aforementioned without departing from the spirit or scope of the invention. Having then described the present invention by reference to certain of its preferred embodiments, it is noted that the disclosed embodiments are illustrative rather than limiting, in fact, and that a wide range of variations, modifications, alterations and substitutions are contemplated in the disclosure. above, and in some examples, some features of the present invention can be employed without corresponding use of the other features. Many such variations and modifications may be considered obvious and desirable by a person skilled in the art on the basis of a review of the aforementioned description of the preferred embodiments. Accordingly, it is appropriate for the appended claims to be interpreted broadly and in a manner consistent with the scope of the invention.
    权利要求:
    Claims (8)
    [0001]
    1. SYSTEM FOR SEATING A WELL HEAD COMPONENT (35) SUBMARINE from a floating drilling platform (11), comprising: a seating tool (31) which has an upper end for coupling to a lowered seating column (19) from the platform (11), the seating tool (31) being adapted to transport and adjust the component in an underwater wellhead; a dynamometer rod (29) that has a bi-directional weight and torque sensor (43), being adapted to be coupled aligned to a portion of a lower end of the laying column (19), and additionally coupled to the laying tool (31 ), so that the dynamometer rod (29) measures a weight and torque applied to the seating tool (31) and produces a signal from the sensor in response; the dynamometer rod (29) comprising: a tubular body (37) having a first portion and a second recessed portion, the second recessed portion defining a recess for coupling the sensor (43); a protective sleeve (47) that circumscribes the second recessed portion of the tubular body (37) and sealsly engaged with the tubular body (37) to protect the sensor from the environment outside the sleeve (47); characterized by an acoustic transmitter (39) being coupled to the dynamometer rod (29) and electrically connected to the torque and weight sensor (43) to receive the sensor signal from the torque and weight sensor (43), the transmitter acoustic (39) being configured to transmit an acoustic signal through the seating column (19); a receiving rod (87) adapted to be coupled in line with a portion of an upper end of the settlement column (19) above sea level; the dynamometer rod (29) is communicatively coupled to the receiving rod (87), so that the receiving rod (87) receives the signal from the dynamometer rod (29); wherein an acoustic receiver (89) is coupled to the receiver rod (87) to receive the acoustic signal from the acoustic transmitter (39); a radio transmitter (91) is connected to the receiving rod (87) and is electrically connected to the acoustic receiver (89) to transmit an RF signal that correlates with the acoustic signal received by the acoustic receiver (89); a radio receiver (123) is arranged on the platform (11) to receive the RF signal from the radio transmitter (91); and the receiving rod (87) is also communicatively coupled to a display (125) located next to a drilling rig operator, so that the receiving rod (87) transmits the signal to the display, where the display is connected to the radio receiver (123) stops to display the signal in real time to an operator on the platform.
    [0002]
    2. SYSTEM, according to claim 1, characterized by the bi-directional weight and torque sensor comprising: a bi-directional load cell that has at least eight strain gauges (43) arranged on two Wheatstone bridges, two strain gauges (43) connected to the stem dynamometer (29) parallel to a geometric axis of dynamometer on diametric sides of the dynamometer rod (29); two extensometers (43) connected to the dynamometer rod (29) perpendicular to the geometric axis of the dynamometer on diametric sides of its dynamometer rod (29), so that the parallel extensometers (43) and the perpendicular extensometers (43) can be coupled communicatively on a first Wheatstone bridge to produce a tension that corresponds to a weight load applied to the dynamometer rod (29); two extensometers (43) connected to the dynamometer rod at an angle of forty-five degrees to a geometric axis perpendicular to the geometric axis of the dynamometer on diametric sides of the dynamometer rod; and two extensometers (43) connected to the dynamometer rod at an angle of forty-five degrees negative to the geometric axis perpendicular to the geometric axis of the dynamometer on diametric sides of its dynamometer rod, so that the extensometers (43) can be communicatively coupled on a second Wheatstone bridge to produce a tension corresponding to a torque load applied to the dynamometer rod (29).
    [0003]
    3. SYSTEM FOR SETTING A WELL HEAD COMPONENT (35) SUBMARINE from a floating drilling platform (11), comprising: a laying column (19) configured to be lowered from the platform (11) to a well head submarine; a seating tool (31) having an upper end coupled to a portion of a lower end of the seating column (19), the seating tool (31) being adapted to transport and adjust the component in a wellhead submarine; the seating tool (31) having a rotating device for exerting an adjusting force in response to rotation; a dynamometer rod (29) which has a bidirectional load cell, the dynamometer rod (29) being coupled in line with the laying column (19) and additionally coupled to the laying tool (31); the dynamometer rod (29) comprising: a tubular body (37) having a first portion and a second recessed portion, the second recessed portion defining a recess for coupling the load cell; and a protective sleeve (47) circumscribing the second recessed portion of the tubular body (37) and sealingly engaged with the tubular body (37) to protect the load cell from the environment outside the sleeve (47); characterized by an acoustic signal transmitter being coupled to a dynamometer rod (29) and to the bidirectional load cell; the acoustic signal transmitter is configured to receive a plurality of load cell signals from the bidirectional load cell and transmit acoustic signals in response through the seating column (19); an acoustic signal receiver coupled to a portion of an upper end of the laying column (19) and adapted to be above sea level to receive the acoustic signals transmitted through the laying column (19); the acoustic signal transmitter being additionally coupled communicatively to the acoustic signal receiver, so that a signal is transmitted from the bidirectional load cell to the acoustic signal transmitter and, later, to the acoustic signal receiver; wherein a radio transmitter (91) is connected to the upper end portion of the seating column (19) and is electrically connected to the acoustic signal receiver to transmit RF signals proportional to the acoustic signals received by the acoustic signal receiver; a radio receiver (123) is arranged on the platform (11) to receive the RF signals; and a display adapted to be located on the platform (11) and configured to display the RF signals received by the radio receiver (123) in a mode understood by an operator on the platform and mounted so that an operator visually monitors the display in real time ; and the acoustic signal receiver communicatively coupled to the display.
    [0004]
    4. SYSTEM, according to claim 3, characterized in that the bidirectional load cell comprises at least eight strain gauges (43) arranged in two Wheatstone bridges.
    [0005]
    5. METHOD FOR SETTING A SUBMARINE WELL HEAD DEVICE (35) of a floating drilling platform (11), characterized by comprising the steps of: (a) providing a weight and torque detection system for a laying tool ( 31) coupled in line with a portion of a lower end of a seating column (19) and the seating tool (31) connected to an underwater wellhead device (35), the weight and torque detection system having a sensor that detects the weight and torque applied in the laying tool (31) and an acoustic transmitter (39), the weight and torque detection system being equipped with a dynamometer rod (29) comprising: a tubular body (37) having a first portion and a second indented portion, the second indented portion defining a recess for coupling the sensor (43); a protective sleeve (47) circumscribing the second recessed portion of the tubular body (37) and sealingly engaged with the tubular body (37) to protect the sensor from the environment outside the sleeve (47); (b) lower the seat post (19) and the detection system below an underwater riser, couple an acoustic receiver (89) and radio receiver (123) aligned to a portion of an upper end of the seat post ( 19) above sea level and position the subsea wellhead device (35) in an engagement with an subsea wellhead assembly (13); (c) operate the seating tool (31) to adjust the subsea device on the wellhead assembly (13); (d) with the sensor, detect weight and torque applied to the laying tool (31), generating an acoustic signal in a bidirectional load cell of the weight and torque detection system in response to the laying tool operation (31) and with the acoustic transmitter (39), transmit the acoustic signals through the seating column (19) proportional to the weight and torque detected; then (e) transmit the signal from a bidirectional load cell of the detection system to a display on the drilling rig, in which with an acoustic receiver (89), receive the acoustic signal, and with a radio transmitter (91), transmitting an RF signal proportional to the acoustic signal to a radio receiver (123) and to the display on the drilling rig of the platform; then (f) communicate the signal to a drill rig operator.
    [0006]
    6. METHOD according to claim 5, characterized in that step (c) comprises rotating the seating column to rotate a portion of the seating tool (31) in relation to the wellhead device (35).
    [0007]
    7. METHOD, according to claim 5, characterized by step (d) comprising: deforming the dynamometer rod (29) of the detection system, the deformation altering a resistance of the bidirectional load cell; and generate the acoustic signal in response to the changed resistance.
    [0008]
    8. METHOD, according to claim 5, characterized by the method further comprising: coupling a weight and surface torque detection system to an upper end of the drilling column (19) above sea level and while performing the step ( ç); generate a surface signal in a bidirectional load cell of the surface weight and torque detection system in response to the operation of the laying tool (31) in step (c); and transmit the surface signal from the bidirectional load cell from the surface weight and torque detection system to the platform.
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    同族专利:
    公开号 | 公开日
    AU2012201259B2|2016-11-10|
    BR102012004766A2|2018-11-27|
    AU2012201259A1|2012-09-20|
    US20120223839A1|2012-09-06|
    CN102654051B|2016-10-19|
    GB2488659B|2016-07-20|
    CN102654051A|2012-09-05|
    GB201203554D0|2012-04-11|
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    MY164511A|2017-12-29|
    US9091604B2|2015-07-28|
    GB2488659A|2012-09-05|
    SG183651A1|2012-09-27|
    NO20120229A1|2012-09-04|
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    法律状态:
    2018-11-27| B03A| Publication of an application: publication of a patent application or of a certificate of addition of invention|
    2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-09-10| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-01-14| B07A| Technical examination (opinion): publication of technical examination (opinion)|
    2020-05-19| B09A| Decision: intention to grant|
    2020-11-03| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 02/03/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US13/040,002|2011-03-03|
    US13/040,002|US9091604B2|2011-03-03|2011-03-03|Apparatus and method for measuring weight and torque at downhole locations while landing, setting, and testing subsea wellhead consumables|
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