• 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:
    method for monitoring a position of a service tool in a downhole, and downhole tool assembly. systems and methods are provided for monitoring a position of a service tool in a wellbore. the service tool may have a sensor assembly attached to it and be positioned within the wellbore. the service tool can be moved inside the wellbore. the distance traveled by the service tool in the wellbore can be measured with the sensor assembly. the position of the service tool in the wellbore can be determined by comparing the distance traveled to a stationary reference point.
    公开号:BR112013018519B1
    申请号:R112013018519-8
    申请日:2012-01-23
    公开日:2021-06-01
    发明作者:Scott Malone；Aleksandar Rudic；Bryan Stamm；Philip Wassouf；Dexter M. Mootoo
    申请人:Prad Research And Development Limited；
    IPC主号:
    专利说明:

    BACKGROUND
    [001] The modalities described here refer generically to monitoring the position of a tool at the bottom of the wellbore in a wellbore. More particularly, the modalities refer to monitoring the position of a service tool during sand control operations.
    [002] Conventional sand control operations include a service tool and a lower completion set. The service tool is attached to the lower completion assembly and the two components are drilled into the hole together. After reaching the desired depth, a plug attached to the lower completion set is placed to secure the lower completion set in the wellbore. After inserting the plug, the service tool is released from the lower completion set. Once released, the service tool can be used in the gravel filling process.
    [003] The gravel filling process requires moving the service tool within the wellbore to align one or more crossing holes in the service tool with one or more completion holes in or above the lower completion assembly. As such, alignment of holes requires precise positioning of the service tool. Downhole forces, however, such as pressure, drag on the drill pipe and/or contraction and expansion of the drill pipe will generally affect the position of the service tool, making it difficult to align the holes. What is needed, therefore, is an improved system and method for monitoring the position of the service tool in the wellbore. SUMMARY
    [004] Systems and methods for monitoring the position of a service tool in a wellbore are provided. In one aspect, the method can be performed by positioning the service tool in the wellbore, and the service tool can have a sensor assembly coupled thereto. The service tool can be moved inside the wellbore. The distance traveled by the service tool in the wellbore can be measured with the sensor assembly. The position of the service tool in the wellbore can be determined by comparing the distance traveled to a stationary reference point.
    [005] In one aspect, the system can include a completion set and a service tool. A plug can be coupled to the completion set and adapted to secure the completion set in a stationary position within a wellbore. The service tool can be attached to the completion set and the service tool can be adapted to release from the completion set after plug clamping. A sensor assembly can be attached to the service tool. The sensor assembly may include a wheel that is adapted to contact and roll along a wall of the wellbore as the service tool moves a distance within the wellbore. The sensor assembly can be adapted to measure the distance traveled by the service tool, and the distance can correspond to numerous revolutions of the wheel. The sensor assembly can be adapted to determine a position of the service tool in the wellbore by comparing the distance traveled to a stationary reference point. BRIEF DESCRIPTION OF THE DRAWINGS
    [006] So that the mentioned features can be understood in detail, a more specific description can be had, briefly summarized above, by reference to one or more modalities, some of which are illustrated in the attached drawings. It should be noted, however, that the accompanying drawings illustrate only typical embodiments and, therefore, should not be considered as limiting their scope, as the invention may support other embodiments that are equally effective.
    [007] Figure 1 represents a cross-sectional view of a downhole tool assembly having a sensor assembly in a disengaged position, according to one or more described modalities.
    [008] Figure 2 represents a cross-sectional view of the downhole tool assembly of Figure 1 having the sensor assembly in an engaged position, according to one or more described modalities.
    [009] Figure 3 represents a perspective view of an illustrative sensor assembly in the disengaged position, according to one or more described modalities.
    [0010] Figure 4 represents a perspective view of the illustrative sensor assembly of Figure 3 in the engaged position, according to one or more described embodiments.
    [0011] Figure 5 represents a perspective view of another illustrative sensor assembly, according to one or more described modalities.
    [0012] Figure 6 represents a cross-sectional view of the sensor assembly of Figure 5, according to one or more described embodiments.
    [0013] Figure 7 represents an illustrative wheel that can be coupled to the sensor assembly, according to one or more described modalities.
    [0014] Figure 8 represents an illustrative sensor arranged close to the wheel of Figure 7, according to one or more described modalities.
    [0015] Figure 9 represents another illustrative sensor assembly, according to one or more described modalities.
    [0016] Figure 10 represents another illustrative sensor assembly, according to one or more described modalities.
    [0017] Figure 11 represents a cross-sectional view of the service tool in a first position in circulation according to one or more described modalities.
    [0018] Figure 12 represents a cross-sectional view of the service tool in a second inversion position according to one or more described modalities.
    [0019] Figure 13 is a cross-sectional view of another illustrative sensor assembly, according to one or more described embodiments. DETAILED DESCRIPTION
    [0020] Figure 1 is a cross-sectional view of a downhole tool assembly 100 having a sensor assembly 110 in a disengaged position, according to one or more embodiments. Downhole tool assembly 100 can include a work string 104, a service tool 106, and a lower completion assembly 108. The work string 104 can be coupled to the service tool 106 and adapted to move the tool. service center 106 axially and rotationally in a 102 wellbore.
    [0021] The service tool 106 may include one or more tool position sensors or sensor assemblies (one is shown) 110 adapted to monitor the position of the service tool 106 in the wellbore 102. If the service tool 106 including multiple sensor assemblies 110, sensor assemblies 110 may be axially and/or circumferentially displaced in service tool 106. Sensor assembly 110 in Figure 1 is shown in the disengaged position meaning that sensor assembly 110 is not in contact. with a wall 112 of the wellbore 102. As used herein, the wall 112 of the wellbore 102 may include an uncoated wall of the wellbore 102 or the inner surface of a casing disposed in the wellbore 102.
    [0022] Figure 2 is a cross-sectional view of the downhole tool assembly 100 having the sensor assembly 110 in an engaged position, according to one or more embodiments. Lower completion assembly 108 can include one or more plugs 114. In at least one embodiment, plugs 114 can be gravel plugs. When the lower completion set 108 has been passed to the desired depth in the wellbore 102, plugs 114 can be placed, as shown in Figure 2, to secure the lower completion set in place and isolate a first upper annular space 116 from a second lower annular space 118.
    [0023] After the shutters 114 have been placed, the sensor assembly 110 may act to the engaged position such that at least a portion of the sensor assembly 110, e.g. a wheel, as further described below, is in contact. with wall 112 of wellbore 102. Sensor assembly 110 may be in the engaged position when service tool 106 is passed to wellbore 102, operated at depth in wellbore 102, e.g., in circulation and reversing, and/or pulled out of wellbore 102. For example, sensor assembly 110 may be in the disengaged position when service tool 106 is passed to wellbore 102 and in the engaged position when service tool 106 is operated deep in wellbore 102 and pulled out of wellbore 102. In another embodiment, sensor assembly 110 may be in the disengaged position when service tool 106 is passed to wellbore 102 at the engaged position while service tool 106 is operated deep in the wellbore, and in the disengaged position when service tool 106 is pulled out of wellbore 102. Sensor assembly 110 can be driven to the engaged position by a motor electric, a solenoid, an actuator (including electric, hydraulic or electro-hydraulic), a timer-based actuator, a spring, pressure inside wellbore 102 or similar. After being in the engaged position, the sensor assembly 110 can maintain contact with the wall 112 of the wellbore 102 through a spring, wedge, actuator, screw jack mechanism, or the like.
    [0024] The sensor assembly 110 can activate and begin taking measures to monitor the position of the service tool 106 in the wellbore 102 when the sensor assembly 110 triggers to the engaged position, i.e., it contacts the wall 112, or sensor assembly 110 may activate at a predetermined, later time. For example, sensor assembly 110 can activate when a predetermined pressure or temperature is reached or when a signal (via cable or wireless) is received.
    [0025] In at least one embodiment, after the sensor assembly 110 is activated, the service tool 106 can release from the lower completion assembly 108 such that the service tool 106 is free to move axially and rotationally in the hole. well 102 with respect to stationary lower completion assembly 108. Sensor assembly 110 may be adapted to take measures to monitor the axial and/or rotational position of service tool 106 as service tool 106 is passed into the bore hole. well 102, operated at depth in wellbore 102, and/or pulled out of wellbore 102.
    [0026] Another embodiment of the sensor assembly 110 can also measure the rotation of the service tool 106 with respect to the lower completion assembly set 108 or reference point 120 in the wellbore 102. In at least one embodiment, the service tool 106 can be released or disconnected from the fixed lower completion assembly 108 by rotating the service tool 106 to unscrew it from the lower completion assembly 108. The sensor assembly 110 may be adapted to measure both axial and rotational movement of the service tool. service 106 with respect to wellbore 102.
    [0027] The position of the service tool 106 in the wellbore 102 can be measured with respect to a reference point 120 having a known position in the wellbore 102. For example, the reference point 120 can be located in the set of stationary bottom completion 108. In at least one embodiment, the service tool 106 can be pulled out of the wellbore 102 after being released from the completion assembly 108, and a second service tool (not shown) can be seated in the hole. of well 102. The second service tool may also have a sensor assembly coupled thereto and utilize the reference point 120 on the lower completion assembly 108.
    [0028] The measurements can be processed in the service tool 106 and/or transmitted to an operator and/or surface recording device via a wire or wireless. For example, measurements can be transmitted through wired drill pipe, work string cable 104, ring space cable 116, acoustic signals, electromagnetic signals, mud pulse telemetry, or the like. Measurements can be processed in service tool 106 and/or transmitted to the surface continuously or intermittently to determine the position of service tool 106 in wellbore 102. In at least one embodiment, time between processing and/or transmitting the measurements can be approximately 0.5s to approximately 2s, approximately 2s to approximately 10s, approximately 10s to approximately 30s, approximately 30s to approximately 60s (1 min.), approximately 1 min. to approximately 5 min., approximately 5 min. to approximately 10 min., approximately 10 min. to approximately 30 min., or more.
    [0029] Figure 3 is a perspective view of an illustrative sensor assembly 300 in the disengaged position, according to one or more embodiments. Sensor assembly 300 may include a housing 302, a motor 304, one or more arms (two are shown) 306a, 306b, and one or more wheels (one is shown) 308. Housing 302 may be coupled or integrated with the tool. point 106 (see figure 1). Housing 302 may be cylindrical with a longitudinal hole 310 extending partially or fully therethrough. Housing 302 may also include a recess 312 in which motor 304, arms 306a, 306b, and wheel 308 are disposed when sensor assembly 300 is in the disengaged position, as shown in Figure 3.
    [0030] Figure 4 is a perspective view of the illustrative sensor assembly 300 of Figure 3 in the engaged position, according to one or more embodiments. To drive the sensor assembly 300 to the engaged position, the motor 304 can move a screw 314 axially along an axis 316 causing the arms 306a, 306b to move the wheel 308 radially outward towards the wall 112 of the bore hole. well 102 (see figure 1). After wheel 308 is in contact with wall 112, motor 304 can be used to control the amount of force applied to wheel 308 to maintain contact between wheel 308 and wall 112. Motor 304 can also be used to retract the wheel 308 back to the disengaged position.
    [0031] Figure 5 represents a perspective view of another illustrative sensor assembly 500, and Figure 6 represents a cross-sectional view of the sensor assembly 500 of Figure 5, according to one or more embodiments. Sensor assembly 500 may include first and second axles 502, 504, one or more springs (one is shown) 506, an arm or yoke 508, a wheel 510, and one or more sensors (one is shown) 512. shaft 502 may extend through a first end 514 of fork 508, and spring 506 may be disposed about first shaft 502. spring 506 may be adapted to actuate and maintain sensor assembly 500 in the engaged position.
    [0032] Second axle 504 can be coupled to and extend through wheel 510 near a second end 516 of fork 508. When in the engaged position, wheel 510 can be adapted to roll against wellbore 102, i.e., roll along wall 112 of wellbore 102 as service tool 106 moves within wellbore 102 (see Figure 1). Second axis 504 may be adapted to rotate through the same angular distance as wheel 510, i.e., one revolution of wheel 510 corresponds to one revolution of second axis 504.
    [0033] In at least one embodiment, one or more magnets (one is shown) 518 may be disposed on or on the second axis 504 and/or the wheel 510 such that the magnet 518 is adapted to rotate through the same angular distance than wheel 510. As magnet 504 rotates, the magnetic field produced by magnet 504 may vary. Sensor 512 may be disposed close to magnet 504 and adapted to detect or measure variations in the magnetic field as magnet 504 rotates. In at least one embodiment, sensor 512 may be disposed in an atmospheric chamber 520. As such, a wall 522 may be disposed between magnet 518 and sensor 512. Atmospheric chamber 520 may be airtight to prevent fluid of wellbore 102 leaks into it.
    [0034] One or more circuits (one is shown) 524 may also be disposed in atmospheric chamber 520 and in communication with sensor 512; however, in at least one modality, sensor 512 and circuit 524 can be a single component. Circuit 524 can be adapted to receive measurements from sensor 512 corresponding to variations in the magnetic field and determine the number of revolutions and/or partial revolutions completed by wheel 510. Circuit 524 can then measure the distance traveled by the service tool 106 in wellbore 102 (see figure 1) based on the number of revolutions and/or partial revolutions completed by wheel 510, as explained in more detail below.
    [0035] The number of revolutions completed by the wheel 510 and/or the distance traveled by the service tool 106 can be transmitted to an operator or surface recording device via a wire or wirelessly. For example, a cable or wire (not shown) may be adapted to receive signals from sensor 512 and/or circuit 524 through a bulkhead 526. The cable may extend through a channel 528 in the yoke 508 and out of a opening 530 through end 514 of yoke 508. In at least one embodiment, yoke 508 may be made of a non-magnetic material. For example, fork 508 can be made of a metallic alloy, such as one or more INCONEL® alloys.
    [0036] Figure 7 represents an illustrative wheel 700 that can be coupled to the sensor assembly 110, 300, 500, according to one or more modalities. After contacting the wall 112 of the wellbore 102 (see Figure 1), the wheel 700 may be adapted to roll against the wellbore 102 when the service tool 106 moves into the wellbore 102. As the wheel 700 rotates, the axial and/or rotational distance traveled by the service tool 106 can be measured, for example, by the sensor 512 and/or circuit 524 in Figure 6. A complete revolution of the wheel 700 represents a distance traveled by the service tool. service 106 calculated by the following equation:

    [0037] where D is the distance, and n is the mathematical constant pi, and R is the radius of the wheel 700. The speed of service tool 106 in wellbore 102 can also be calculated by the following equation: V = D/t
    [0038] where V is speed, D is distance, and t is time. Acceleration can also be calculated by the following equation: A = V/t
    [0039] where A is the acceleration, V is the velocity and t is time.
    [0040] The radius R of wheel 700 is a known quantity and can range from as low as approximately 0.05 cm, approximately 1 cm, approximately 2 cm, or approximately 3 cm to as high as approximately 5 cm, approximately 10 cm, approximately 20 cm, approximately 40 cm, or more. For example, the radius R of wheel 700 can range from approximately 1 cm to approximately 3 cm, approximately 3 cm to approximately 6, approximately 6 cm to approximately 10 cm, or approximately 10 cm to approximately 20 cm.
    [0041] One or more targets (six are shown) 702a-f may be arranged at different circumferential positions on wheel 700. As the number of targets 706a-f increases, the accuracy of the distance measurement D may also increase. The distance D traveled by the service tool 106 can be calculated by the following equation:

    [0042] where S is the number of 702a-f targets detected or counted by the sensor, for example, sensor 800 in figure 8, and N is the total number of 702a-f targets arranged on the wheel 700. For example, if the wheel 700 rotate half a revolution, the distance D traveled by the service tool 106 is equal to (2*n*R*3)/6 because the exemplar wheel 700 includes 6 targets, and 3 targets will be detected or counted when the wheel 700 rotate half a revolution. The number N of targets 702a-f arranged on wheel 700 can range from as low as approximately 1, approximately 2, approximately 3, approximately 4, or approximately 5 to as high as approximately 6, approximately 8, approximately 10, approximately 12, approximately 24 or more. For example, the number N of 702a-f targets can be from approximately 1 to approximately 12, from approximately 2 to approximately 10, or from approximately 4 to approximately 6.
    Targets 702a-f may be disposed at the axial or lateral end 704 of wheel 700, as shown, or targets 702a-f may be disposed at radial end 706 of wheel 700. For example, targets 702a-f may be disposed in one or more recesses (not shown) in the radial end 706 of wheel 700 so that the targets 702a-f do not come into direct contact with the wall 112 of the wellbore 102 (see Figure 1) as the wheel 700 rotates. In at least one embodiment, the radial end 706 of the wheel may include a coating or layer having a high coefficient of friction that prevents the wheel 700 from slipping or slipping as the wheel 700 rotates along the wall 112 of the wellbore 102. The coating or layer can also have high wear resistance to improve longevity.
    [0044] Figure 8 represents an illustrative sensor 800, arranged near the wheel 700 of Figure 7, according to one or more modalities. Sensor 800 may be disposed on sensor assembly 110, 300, 500 such that sensor 800 is stationary with respect to rotating wheel 700. In addition, sensor 800 may be disposed on sensor assembly 110, 300, 500 of such that sensor 800 can detect or count targets 702a-f on wheel 700 as targets 702a-f pass sensor 800 as wheel 700 rotates. Thus, sensor 800 may be disposed near side 704 of wheel 700 if targets 702a-f are disposed on side 704 of wheel 700, as shown in Figure 7, or sensor 800 may be disposed near radial end 706 of wheel 700 if targets 702a-f are disposed on radial end 706 of wheel 700.
    [0045] The communication between the 702a-f targets and the 800 sensor can be magnetic, mechanical, optical or direct contact. For example, targets 702a-f can be magnets, as described above. In another embodiment, the 702a-f targets can be radio frequency identification tags (RFID). The distance between the 800 sensor and the 702a-f targets can range from low of approximately 0 cm (direct contact), approximately 0.1 cm, approximately 0.2 cm, or approximately 0.3 cm to high of approximately 0.5 cm, approximately 1 cm, approximately 5 cm, approximately 10 cm, or more. For example, the distance between sensor 800 and targets 702a-f can be approximately 0 cm to approximately 0.2 cm, approximately 0.2 cm to approximately 0.5 cm, approximately 0.5 cm to approximately 1 cm, or approximately 1 cm to approximately 4 cm.
    [0046] Figure 9 represents another illustrative sensor assembly 900, according to one or more embodiments. Sensor assembly 900 may include a wheel 902, an axle 904, and a sensor 906 disposed in a housing 908. In the engaged position, the wheel 902 may be in contact with the wall 112 of the wellbore 102 (see Figure 1 ) and adapted to rotate when service tool 106 moves within wellbore 102. Shaft 904 may be coupled to wheel 902 and adapted to rotate through the same angular distance as wheel 902. Shaft 904 may be in communication with sensor 906 in housing 908. Sensor 906 can measure the number of revolutions and/or partial revolutions of shaft 904, which can be used to calculate the distance D traveled by service tool 106 in wellbore 102 (see Figure 1 ). The 906 sensor can include a gear tooth counter, an optical encoder, a mechanical encoder, a contact encoder, a resolver, a rotary variable differential transformer (RVDT), a synchro , a rotary potentiometer or similar.
    [0047] Figure 10 represents another illustrative sensor assembly 1000, according to one or more modalities. Sensor assembly 1000 may include a wheel 1002, a shaft 1004, a gear 1006, a sensor 1008, and a housing 1010. In the engaged position, the wheel 1002 may be in contact with the wall 112 of the wellbore 102 (see Figure 1) is adapted to rotate when service tool 106 moves within wellbore 102. Shaft 1004 can be coupled to wheel 1002 and adapted to rotate through the same angular distance as wheel 1002. sensor 1008 may be disposed in housing 1010, and a seal 1012, such as a swivel seal, may be used to prevent fluid from entering housing 1010.
    [0048] Gear 1006 may be coupled to shaft 1004 and adapted to rotate through the same angular distance as shaft 1004. Gear 1006 may include one or more teeth 1014 disposed on an outer radial or axial surface thereof. The number of teeth 1014 can range from as low as approximately 1, approximately 2, approximately 4, approximately 5, or approximately 6 to as high as approximately 8, approximately 10, approximately 12, approximately 20, approximately 24 or more. For example, the number of teeth 1014 can range from approximately 1 to approximately 4, from approximately 4 to approximately 8, from approximately 8 to approximately 12, or from approximately 12 to approximately 24.
    [0049] Sensor 1008 may be in direct or indirect contact with gear 1006 and adapted to detect or count the number of teeth 1014 that pass as gear 1006 rotates. This measurement can be used to calculate the distance D that the service tool 106 moves in the wellbore 102. This measurement can also be used to calculate the velocity V and/or the acceleration A of the service tool 106 in the wellbore 102. In at least one embodiment, gear 106 can be in direct contact with wall 112 of wellbore 102, and sensor 1008 can be exposed, i.e., not disposed within housing 1010.
    [0050] Figure 11 represents a cross-sectional view of the service tool 106 in a first position in circulation according to one or more described modalities. After the shutters 114 have been placed and the sensor assembly 110 is in the engaged and activated position, the service tool 106 can be released from the lower completion assembly 108. Once released, the probe elevators (not shown) can move the tool service tool 106 in wellbore 102. As service tool 106 moves, sensor assembly 110 can measure the distance traveled by service tool 106 in wellbore 102. For example, distance traveled can correspond to the number of wheel revolutions 308, 510, 700, 902, 1002 in sensor assembly 110. The position of service tool 106 in wellbore 102 can then be determined with respect to stationary reference point 120.
    [0051] At least one of (1) the distance traveled by the service tool 106 and (2) the position of the service tool 106 can be transmitted to an operator or surface recording device. After the distance traveled by the service tool 106 and/or the position of the service tool 106 are known, the operator or engraving device can move the service tool 106 to precise locations within the wellbore 102. For example, the engraving tool service 106 can be moved to the first circulation position to align one or more of the crossing holes 130 (see Figure 12) arranged through the service tool 106 with one or more completion holes 132 disposed through the lower completion assembly 108 .
    [0052] The distance that the service tool 106 needs to travel, for example, the distance between holes 130, 132 when the service tool 106 is released from the lower completion set 108, may be a known quantity. Sensor assembly 110 can then measure the distance that service tool 106 travels to facilitate alignment of holes 130, 132. For example, the distance between crossing hole 130 and completion hole 132 can be 1 m when service tool 106 is released from lower completion set 108. If radius R (also a known quantity) of wheel 308, 510, 700, 902, 1002 in sensor set 110 is 10 cm (0.1 m), a single revolution of the wheel 308, 510, 700, 902, 1002 represents a distance D traveled calculated by the following equation:

    [0053] The number of revolutions that the wheel 308, 510, 700, 902, 1002 will have to complete to move the service tool 1 m can be calculated by the following equation:
    [0054] (0.628 m) / (1 revolution) = (1 m)/(X revolutions)
    [0055] In this exemplary mode, X is equal to approximately 1.6 revolutions, and thus, when wheel 308, 510, 700, 902, 1002 completes approximately 1.6 revolutions, service tool 106 will have moved 1 m, and holes 130, 132 will be aligned.
    [0056] After aligning the holes 130, 132, the lower annular space 118 can be filled with gravel. A treatment fluid, such as a gravel slurry including a mixture of a carrier fluid and gravel, may flow through the service tool 106, through the holes 130, 132, and into the lower annular space 118 between one or more screens 134 in the lower completion assembly 108 and the wall 112 of the wellbore 102. A gravel slurry carrier fluid may flow back into the service tool 106 leaving the gravel disposed in the annular space 118. The gravel forms a permeable mass or "seal" between one or more screens 134 and wall 112 of wellbore 102. The gravel seal allows production fluids to flow therethrough while substantially blocking the flow of any particulate material, e.g., sand.
    [0057] At certain times during use of the service tool 106, the service tool 106 may move axially within the wellbore 102 due to various forces acting on it. Forces can include pressure, drag on workstring 104, and contraction and expansion of workstring 104 due to changes in temperature. For example, during the circulation process, net pressure forces on service tool 106 can push service tool 106 up into wellbore 102. This upward movement of service tool 106 can be compounded by contraction of the column. 104 as it cools during pumping. Sensor assembly 110 can be used to determine the position of service tool 106 in wellbore 102 both axially and rotationally, and in response to the determined position, additional weight and/or rotation can be added or removed on the surface to maintain the service tool 106 in the desired position, eg with holes 130, 132 aligned. Monitoring the position of the service tool 106 and the corresponding variation in surface weight can be used for other operations as well, including when the service tool 106 is in the release, compression, discharge seal, or inversion secondary positions.
    [0058] Figure 12 represents a cross-sectional view of the service tool 106 in a second inversion position according to one or more modalities. After circulation of the service fluid, the service tool 106 can move within the wellbore 102 to an inversion position where the crossing hole 130 is positioned above the plugs 114. For example, the distance between the crossing hole 130 and shutters 114 may be 2 m, and as such, an operator may decide that the service tool needs to be moved upward 2.5 m to place the crossing hole 130 above the shutters 114. Continuing with the above example having a wheel with a radius R of 10 cm, the number of revolutions that the wheel 308, 510, 700, 902, 1002 will have to complete to move the service tool 2.5 m can be calculated by the following equation: (0.628 m)/ (1 revolution) = (2.5 m)/(X revolutions)
    [0059] where X is the number of revolutions of the wheel. For example, when X equals approximately 4 revolutions, and thus, when wheel 308, 510, 700, 902, 1002 completes approximately 4 revolutions, service tool 106 will have moved 2.5 m, and the cross hole 130 will be in the desired position above shutters 114.
    [0060] Once in the inversion position, pressure can be applied to the annular space 116 to invert the gravel paste remaining in the service tool 106 back to the surface. The high pressure in the annular space 116 can force a wellbore fluid in the annular space 116 through the orifice 130, thereby forcing the gravel slurry in the service tool 106 to the surface. With the position of the service tool 106 known, pumping can begin as soon as the service tool 106 enters the reversing position and before the annular pressure is fully bled.
    [0061] Figure 13 is a cross-sectional view of another illustrative sensor assembly 1300, according to one or more embodiments. Sensor assembly 1300 may be coupled to or integrated with service tool 106. For example, sensor assembly 1300 may include a housing 1301 having first and second connectors 1302, 1304 adapted to connect sensor assembly 1300 to the service tool. service 106. Sensor assembly 1300 may also include a bore 1306 extending partially or entirely therethrough. At least a portion of sensor assembly 1300 can include a compensator 1308 that extends radially outward from the remaining portion of sensor assembly 1300.
    [0062] The sensor assembly 1300 may include an arm or yoke 1310 having a wheel 1312 coupled thereto. Fork 1310 and wheel 1312 may be substantially similar to fork 508 and wheel 510 described above, and thus will not be described again in detail. One or more electronic components 1314 may be disposed in housing 1301. Electronic components 1314 may include one or more circuitry adapted to receive data from wheel 1312, e.g., the number of revolutions. In at least one embodiment, the electronics 1314 can be adapted to measure the distance traveled by the service tool 106 based on data from the wheel 1312. In another embodiment, the electronics 1314 can be adapted to measure the distance traveled by the service tool. service 106 and determine the position of the service tool 106 in the wellbore 102 based on the distance measurements. As described above, the electronics can be adapted to transmit the distance traveled and/or the position of the service tool 106 in the wellbore to an operator or surface recording device.
    [0063] One or more batteries 1316 may also be arranged in housing 1301. For example, batteries 1316 may form an annular battery group in housing 1301. Batteries 1316 may be adapted to supply power to fork 1310, the motor driving the yoke 1310, the electronics 1314, or other downhole devices.
    [0064] Referring again to Figures 1, 2, 11 and 12, the sensor assembly 110 can be used to monitor and identify when the service tool 106 starts, stops, or otherwise moves, to more accurately determine the weights up, down and neutrals used on the surface. This data can then be correlated against engineering prediction models, real-time or historical post-job matching to calibrate the models. Calibration can be achieved by varying one or more variables, such as fluid/pumping viscous friction factors in the casing or an open hole section, until the prediction matches the actual measurement.
    [0065] The sensor assembly 110 described here can be used by any downhole tool to measure downhole distances and determine downhole positions. For example, sensor assembly 110 can be used in a centralizer used in other cable tools, measurement and drilling logging tools, offset tools, and fishing tools that are used to, for example, profile information about the adjacent formation or map the adjacent formation. As such, the position of the downhole tool can be correlated with logs, maps or the like.
    [0066] Alternative technologies for measuring and monitoring the position of service tool 106 in wellbore 102 may include acoustic, magnetic and electromagnetic techniques. The position of service tool 106 can also be measured and monitored with a linear variable differential transformer or a tether or cable coupled to service tool 106. For example, one end of a tether can be coupled to service tool 106, and the other end of the lanyard may be coupled to the stationary lower completion assembly 108 or stoppers 114. The lanyard may be tensioned as the service tool 106 moves into the wellbore 102. Thereby, as the lanyard tool service 106 moves with respect to stationary lower completion assembly 108 or shutters 114, tether length may vary. The length of the lanyard can be measured to determine the position of the service tool 106 in the wellbore 102. Upon completion of the work, the lanyard can be released or cut from the lower completion assembly 108 or plugs 114 allowing the service tool 106 to is pulled out of wellbore 102.
    [0067] In another embodiment, the sensor assembly 110 may include an acoustic sensor or transceiver, and the reference point 120 may include a target. Target 120 can be placed in stationary lower completion assembly 108 or shutters 114. Sensor assembly 110 can be adapted to send acoustic signals to and receive acoustic signals from target 120. The signals can be used to determine a distance traveled by the tool of service 106 and/or position of service tool 106 and wellbore 102. At least one of the distance traveled and position of service tool 106 can then be transmitted to an operator or recorder on the surface, and after the position is known or determined (based on the distance travelled), the service tool 106 can be moved to precise locations in the wellbore 102.
    [0068] Several terms have been defined above. To the extent that a term used in a claim is not defined above, it shall be given the broadest definition that persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. In addition, all patents, testing procedures and other documents cited in this application are fully incorporated by reference to the extent that such disclosure is not inconsistent with that application and for all jurisdictions in which such incorporation is permitted.
    [0069] Although the above is directed to embodiments of the present invention, other embodiments and additional embodiments of the invention can be devised without departing from the basic scope thereof, and the basic scope thereof is determined by the claims that follow.
    权利要求:
    Claims (17)
    [0001]
    1. A method for monitoring a position of a service tool (106) in a wellbore (102), comprising: positioning the service tool (106) having a sensor assembly (110) coupled thereto within the wellbore (102), wherein the sensor assembly (110) comprises a wheel that rolls against the wellbore as the service tool moves within the wellbore; moving the service tool (106) into the wellbore (102); measuring a distance traveled by the service tool (106) in the wellbore (102) with the sensor assembly (110); by determining the position of the service tool (106) in the wellbore (102) by comparing the distance traveled to a stationary reference point (120), where the distance traveled corresponds to a number of revolutions of the wheel (510), characterized by detecting variations in a magnetic field produced by a magnet (518) that rotates through the same angular distance as the wheel (510), wherein the magnet (518) is disposed on or on an axis (504) that extends through the wheel (510).
    [0002]
    2. Method according to claim 1, characterized in that the sensor assembly C comprises an acoustic sensor.
    [0003]
    3. Method according to claim 1, characterized in that the measured distance is at least one of an axial distance and a rotational distance.
    [0004]
    4. The method of claim 1, further comprising calculating at least one of a speed of the service tool (106) in the wellbore (102) and an acceleration of the service tool (106) in the well hole (102).
    [0005]
    5. Method according to claim 1, characterized in that the stationary reference point (120) is arranged in a stationary completion set (108).
    [0006]
    6. Method according to claim 1, characterized in that it further comprises: transmitting at least one of the measured distance and position of the service tool (106) to at least one of an operator and a recorder; and moving the service tool (106) to the wellbore (102) in response to at least one of the transmitted distance traveled and the transmitted position of the service tool (106).
    [0007]
    7. Method according to claim 1, characterized in that the service tool (106) comprises at least one of a wire rope tool, a displacement tool, a fishing tool and a shaping tool. measuring and drilling.
    [0008]
    8. Method for monitoring a position of a service tool (106) in a wellbore (102), characterized in that it comprises: passing a downhole tool assembly (100) to the wellbore (102 ), wherein the downhole tool assembly (100) comprises the service tool (106) coupled to a completion assembly (108), wherein the service tool (106) comprises a sensor assembly (110) , and wherein the completion assembly (108) comprises an obturator (114); placing the plug (114) in a fixed position in the wellbore (102), thereby making the completion assembly stationary (108) within the wellbore (102); actuating the sensor assembly (110) to an engaged position such that a wheel (510) of the sensor assembly (110) is in contact with a wall (112) of the wellbore (102); releasing the service tool (106) from the completion assembly (108) after the plug (114) is placed such that the service tool (106) is adapted to move into the wellbore (102) with respect to the assembly stationary completion (108); moving the service tool (106) into the wellbore (102) with respect to the stationary completion assembly (108), wherein the wheel (510) is adapted to roll along the wall (112) of the wellbore ( 102) as the service tool (106) moves; measuring a distance traveled by the service tool (106) in the wellbore (102), the distance corresponding to a number of revolutions of the wheel (510); and determining the position of the service tool (106) in the wellbore (102) relative to the fixed position of the completion assembly.
    [0009]
    9. Method according to claim 8, characterized in that it further comprises transmitting at least one of the distance traveled by the service tool (106) in the wellbore (102) and the position of the service tool (106) in the wellbore (102) for at least one of an operator and a logger.
    [0010]
    10. Method according to claim 9, characterized in that it further comprises moving the service tool (106) in the wellbore (102) in response to at least one of the transmitted distance traveled and the transmitted position of the service tool. service (106) to align one or more crossover holes (130) disposed through the service tool (106) with one or more completion holes (132) disposed through the completion assembly (108).
    [0011]
    11. The method of claim 10, further comprising flowing a treatment fluid through the one or more crossing holes (130) and the one or more completion holes (132) and into an annular formed between the completion assembly (108) and the wall (112) of the wellbore (102) and below the plug (114).
    [0012]
    12. Method according to claim 11, characterized in that it further comprises moving the service tool (106) to an inverted position such that the one or more crossing holes (130) are arranged above the shutter (114).
    [0013]
    13. Downhole tool set (100), characterized in that it comprises: a completion set (108); a shutter (114) coupled to the completion set (108) and adapted to secure the completion set (108) in a stationary position within a wellbore (102); a service tool (106) coupled to the completion set (108), the service tool (106) being adapted to release from the completion set (108) after the plug (114) is secured; and a sensor assembly (110) coupled to the service tool (106), wherein the sensor assembly (110) comprises a wheel (510) that is adapted to contact and roll along a wall (112) of the bore hole. wellbore (102) as the service tool (106) moves a distance within the wellbore (102), wherein the sensor assembly (110) is adapted to measure the distance traveled by the service tool (106) , wherein the distance corresponds to a number of revolutions of the wheel (510), and wherein the sensor assembly (110) is adapted to determine a position of the service tool (106) in the wellbore (102) by comparing the distance traveled to a stationary reference point (120).
    [0014]
    14. Assembly (100) according to claim 13, characterized in that the sensor assembly (110) further comprises: an axle (504) extending through the wheel (510); and a magnet (518) disposed on or on at least one of the axle (504) and the wheel (510), wherein the magnet (518) is adapted to rotate through the same angular distance as the wheel (510).
    [0015]
    15. Assembly (100) according to claim 14, characterized in that the sensor assembly (110) further comprises a sensor (512) adapted to detect variations in a magnetic field produced by the magnet (518) as it the magnet rotates.
    [0016]
    16. Set (100) according to claim 15, characterized in that it further comprises a circuit in communication (524) with the sensor (512).
    [0017]
    17. Assembly (100) according to claim 16, characterized in that at least one of the sensor (512) and circuit (524) is arranged in an atmospheric chamber (520).
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    RU2562292C2|2015-09-10|
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    法律状态:
    2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-10-22| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-12-01| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application [chapter 6.1 patent gazette]|
    2021-03-16| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2021-06-01| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 23/01/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
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    US13/355,067|2012-01-20|
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