RU2729087C1 - Measurement of stress in working string during well completion operations - Google Patents

Abstract

FIELD: measurement.SUBSTANCE: group of inventions relates to a measuring device for measuring stress in a working string during completion operations when fastening a shell for completing a well in a wellbore, methods of installing a shell for completing a well in a wellbore, a method of assessing the integrity of a suspended device for a blind casing string. Measuring device for measuring stress in a working string during completion operations when fastening a shell for completing a well in a wellbore comprises: housing with multiple recesses on housing outer surface; strain gauges, which detect compression, voltage and torque of the housing, applied to the shell for completion of the well during manipulations with the working string during descent; a hydraulic pulse generator which is configured to transmit data received from the strain gauges to the surface controller by telemetry over the hydraulic pulse communication channel; and through hole, which passes through housing and has constant inner diameter. Strain gauges are located in at least two of multiple recesses and said at least two recesses are located in circumferential direction at equal distance from each other along circumference of housing. Hydraulic pulse generator is located in the other one of the plurality of recesses.EFFECT: technical result consists in improvement of efficiency of measurement of torque and load applied by working string during well completion operations.11 cl, 4 dwg

Description

AREA OF TECHNOLOGY

[0001] This invention relates generally to oilfield equipment and, in particular, to downhole tools, well completion systems, and methods for measuring stress (eg, torque, load, etc.) in a work string.

LEVEL OF TECHNOLOGY

[0002] In order to produce formation fluids from the earth formation, wellbores can be drilled deep into the earth formation to the required depth to produce formation fluids. After the wellbore is drilled, casing strings may be installed in the wellbore to stabilize the wellbore and prevent the wellbore from collapsing in the well. A variety of casing strings can be used to complete a deep wellbore. The small space between the casing and the untreated walls of the wellbore (commonly referred to as the annulus) can be filled with cement. After the casing is cemented in place, perforating gun assemblies can be used to perforate the casing and associated cement into the earth formation.

[0003] Some casing strings are referred to as "blind casing strings", which are suspended from an existing casing string at a desired location downhole. Installing a "blind casing" in an existing casing string may involve transferring torque to the working string and applying a load from the working string to install the blind casing. The amount of torque and / or load applied to the liner casing can be valuable information when installing the liner casing in an existing casing string.

[0004] Therefore, it will be understood that improvements are continually needed in the areas of torque and / or load measurement applied by the workstring during well completion operations.

brief description of graphic materials

[0005] Various embodiments of the present invention may be better understood from the detailed description below and accompanying drawings for various embodiments of the invention. In the drawings, like reference numbers may indicate identical or functionally similar elements. Embodiments of the invention are described in detail below with reference to the accompanying figures, with:

[0006] in FIG. 1 illustrates an exemplary partial cross-sectional view of a system for installing a countersunk casing in a wellbore, in accordance with one or more exemplary embodiments of the invention;

[0007] in FIG. 2 illustrates a typical partial cross-sectional view of a portion of the system of FIG. 1 with a measuring device and a bleed tool used to install the plug;

[0008] in FIG. 3 illustrates a typical partial cross-sectional view of a portion of the system of FIG. 1 with a measuring device and a running tool used to set the countersunk casing;

[0009] in FIG. 4 is a perspective view of the measuring tool illustrated in FIG. 3.

detailed description of the invention

[0010] In the present invention, reference numerals and / or letters may be repeated in various examples or in various figures. Such repetition is intended for simplicity and clarity, and does not in itself dictate the relationship between the various embodiments and / or configurations that have been discussed. In addition, spatially relative terms such as below, below, below, above, upper, uphole, downhole, upstream, downstream, and the like may be used herein for ease of description to describe the relationship one element or feature to another element (s) or feature (s), as shown, the upward direction is directed to the top of the corresponding figure, and the downward direction is directed to the bottom of the corresponding figure, the upward direction is towards the wellbore surface, the downward direction is toward bottomhole section of the wellbore. Unless otherwise indicated, spatially relative terms are intended to encompass various orientations of the device in use or operation in addition to the orientation depicted in the graphics. For example, if the device in the figures is inverted, elements described as being “below” or “below” other elements or features will then be oriented “above” other elements or features. Thus, the exemplary term "below" can encompass both the above orientation and the below orientation. The device may be oriented differently (rotated 90 degrees or in other orientations), and spatially relative descriptive terms used herein may also be construed accordingly.

[0011] In addition, even if the figure may depict a horizontal wellbore or a vertical wellbore, unless otherwise indicated, those skilled in the art would appreciate that the apparatus of the present invention is equally well suited for use in wellbores having other orientations including vertical wellbores, deviated wellbores, multilateral wellbores, or the like. Likewise, unless otherwise indicated, even if the figure may depict an offshore operation, those skilled in the art will appreciate that the method and / or system of the present invention is equally well suited for use in onshore operations and vice versa.

[0012] Used in this document, the words "contain", "have", "include", and all grammatical variations thereof have an open, non-limiting meaning that does not exclude additional elements or steps. Although compositions and methods are described using terms such as "comprising", "comprising" or "comprising" various components or steps, compositions and methods can also "consist essentially of" or "consist of" various components and stages. It should also be understood that as used herein, the terms "first", "second" and "third" are arbitrarily assigned and are intended merely to distinguish two or more objects, etc., as the case may be, and are not intended to indicate any sequence. In addition, it should be understood that the simple use of the word “first” does not require any “second” element, and the simple use of the word “second” does not require any “first” or “third” element, etc.

[0013] The terms in the claims have their simple, ordinary meaning, unless otherwise explicitly and clearly defined by the patentee. In addition, the terms in the claims in the singular are defined herein as meaning one or more elements that it introduces. If there is any conflict in the use of a word or term in this description and one or more patents or other documents that may be incorporated herein by reference, definitions should be adopted that are consistent with this description.

[0014] Basically, the present invention provides a measuring device and method for measuring stress (such as compression or tensile stress and / or torque) in a work string during completion operations while attaching a completion to a casing in a wellbore. The completion tool can be at least one of a countersunk casing, a liner hanger, a bridge plug, a fracturing plug, a whipstock, a packer, a sand screen, a milling tool, a fishing tool, a diverter, a device for well completion, anchor device, etc. Attaching the completion tool to the casing (or other tubing strings in the wellbore) may involve manipulating the work string to transfer voltage to the completion tool through a measuring tool, the measuring tool the tool measures the stress applied to the completion tool. The measuring device may comprise a hollow body with a plurality of recesses on the outer surface, with strain gauges located in some of the recesses. The measuring device may comprise a telemetry device (such as a hydraulic pulse generator, an acoustic telemetry device, an electromagnetic telemetry device, an electrical signal telemetry device, and an optical telemetry device) configured to transmit data received from the strain gauges to a surface controller using telemetry, moreover, the telemetry device is located in one of the plurality of recesses. Load cells can measure compression or stress and / or torque in the working string and telemetry the data back to the surface for evaluation. The measurement device may include a through hole that extends through the body and has a substantially constant bore that allows the drop ball to pass through the measurement device and actuate other downhole tools in the borehole that are located deeper in the wellbore than the measurement device. As used herein, the term "drop ball" or "ball" refers to any object that can be moved through the casing to actuate a downhole tool (e.g. running tool 24), and the object can be a ball, dart, plug, etc. P.

[0015] A casing is a tubing that is installed within a drilled wellbore to protect and support production of fluids to the surface. In addition to providing stabilization and containment of the wellbore walls from collapses, the casing can protect the production of fluids from external contaminants, for example, by separating any fresh water reservoirs from the fluids produced through the casing. Also known as casing, casing a wellbore involves running a pipe (such as steel pipe) down the interior of a newly drilled section of a wellbore. The annular space between the casing and the untreated walls of the wellbore can be filled with cement to permanently set the casing in place. The casing can be run from the rig site, connected one at a time at each joint, and driven with the lower end into the casing that was previously inserted into the wellbore. The casing is lowered when the casing load is transferred to casing hangers that are located near the top of the new casing and may use wedges or threads to suspend the new casing in the wellbore. The working string can be used to set the casing near the lower end of a previously installed casing. The slurry can then be pumped into the wellbore and allowed to harden to permanently hold the casing in place. After the cement has solidified, the lower part of the wellbore can be drilled and the completion process continued.

[0016] Sometimes the wellbore is drilled in stages. The wellbore can be drilled to a specific depth, cased and cemented, and then drilled to a greater depth, cased and cemented again, and so on. Each time the wellbore is cased, a smaller diameter casing is used. The widest type of casing can be referred to as guide casing, and is typically 0.8 to 1 m (30 to 42 inches) in diameter for offshore wellbores and 0.3 m to 0.4 m (12 to 16 inches) in diameter for surface wellbores. The annulus radially outside of the casing guide can be filled with cement to prevent circulation of drilling fluids outside the casing guide and erosion. The following casing sizes can be referred to as surface casing , which can be up to several hundred meters (thousands of feet) in length. The annulus in the radial direction outside the surface of the surface casing can be filled with cement to prevent hydrocarbon fluids from entering fresh water zones. In some wellbores, an intermediate casing may be run to separate difficult zones or problem zones, such as high pressure zones or lost circulation zones. The annular space in the radial direction outside the intermediate siege string may be at least partially filled with cement to isolate formations that may collapse and result in lost circulation in the wellbore.

[0017] Typically, the last type of casing to be run into the wellbore is production casing and is therefore the smallest diameter casing. The production casing can be run directly into the reservoir. The annular space in the radial direction outside the production casing may be at least partially filled with cement to prevent hydrocarbons from migrating into lost zones and to prevent formation rocks from collapsing into the wellbore, which can lead to mud losses in the wellbore. In addition, a countersunk casing can be run into the wellbore instead of the casing. While the liner casing is very similar to other casing strings in that it can be made up of separate pipe sections, the liner does not run the entire length of the wellbore. The liner casing can be suspended in the wellbore with a liner casing hanger, and then the annulus radially outside the liner casing can be at least partially filled with cement. A production string can then be run down the wellbore to produce fluids and deliver them to the surface and rig.

[0018] FIG. 1 illustrates a partial cross-sectional elevation view of a wellbore system 10 that may be used for completion operations in wellbore 12. The wellbore 12 may pass through various layers of the subsurface in an oil and gas bearing formation 14 located below the surface 16 of the subsurface. The wellbore system 10 may include a drilling rig (or derrick) 18 and a wellhead 40. A transport device 30 (eg, segmented tubing, coiled tubing, etc.) can be used to transport completion tools and / or casing downhole. In the example illustrated in FIG. 1, the transport device 30 may generally be referred to as workstring 30. Workstring 30 may have a measurement device 50 attached to its lower end by a runner 24 attached between the measurement device 50 and a flush casing 28. Running tool 24 may be attached to the liner 28 on the rig 18 and is used to run the liner 28 into the wellbore 12 via the workstring 30. As illustrated in FIG. 1, a running tool 24 is attached to the upper end of the liner 28 and the workstring 30 is used to position the upper end of the liner 28 above but near the lower end of the casing 34.

[0019] Once the liner 28 is properly positioned in the wellbore 12, the running tool 24 can be used to install a liner hanger 21 (which may contain packers and / or wedges 20, 22) that will hold the liner. the casing 28 in the desired position in the wellbore 12. Once the liner hanger 21 has been installed, the running tool 24 can be released from the liner 28 and the workstring 30, together with the measuring device 50 and the running tool 24, can be removed from the borehole 12, with the liner 28 remaining in the wellbore 12. However, prior to removal of workstring 30 from wellbore 12, cement may be pumped through workstring 30, measurement tool 50, and running tool 24 to fill the annulus between liner 28 and wellbore 12. Packers and / or wedges 20, 22 may represent any suitable type of packer or wedge that can securely anchor the top end of the liner 28 to the casing 34. For example, inflatable, swellable, compressible, and / or mechanical packers may be included in the liner hanger 21. Mechanically expandable wedge grips, hydraulically expandable wedge grips, rotating activated wedge grips, etc. can also be included in the hanger 21 for the countersunk casing. Packers and grips are well known in the art and will not be discussed further.

[0020] FIG. 2 illustrates an embodiment of the present invention for installing a plug 90 in a wellbore 12. The fracturing operation is depicted in FIG. 2, where fracture 94 is fractured in section 98 through perforations 86. For fracture section 96, the previous fracture 94 is typically isolated from a new fracture 92 that may be generated through additional perforations 86 in section 96. In this completion operation with treatment and / or fracturing the wellbore 12 can be used to install a bridge plug or fracture plug 90 in the wellbore 12 between sections 96 and 98 to withdraw the near-wellbore treatment compound or fracturing fluid in the perforation 86 in section 96. The working string 30 may contain a measuring device 50 and a run a tool 24 attached to the end of the work string 30 with a plug 90 attached to the running tool. Centralizer 82 can be used to center the workstring 30 in the wellbore 12. The plug 90 can be delivered to the wellbore 12 via the workstring 30 and installed between the sections 96 and 98 using the running tool 24. The measuring device 50 can measure the compression, stress and torque applied to the plug 90 by the workstring 30 during the installation of the plug and, possibly after installing the plug to check the seal integrity of the plug on the casing 34 in the wellbore 12. As used herein, the term "plug" refers to a bridge plug, fracture plug, whipstock, or any other device that can be run into a wellbore and installed with a running tool 24.

[0021] FIG. 3 illustrates an embodiment of the present invention for installing a countersunk casing 28 in a wellbore 12, similar to the configuration illustrated in FIG. 1. Measuring device 50 may be connected to flush 24 through threaded connections 54 and 56, with threaded connection 53 being used to connect measuring device 50 to workstring 30. It will be appreciated that threaded connections 53, 54, 56 may implement other connections, for example, additional pipe sections may be connected between measuring device 50 and venting tool 24, and also between measuring device 50 and workstring 30.

[0022] As previously indicated, the running tool 24 can be attached to the upper end of the liner 28. The liner 28 can be run into the wellbore 12 and positioned near the lower end of the casing 34 (or any other desired location along the casing columns 34). Meter 50 may include a plurality of sensors for measuring and monitoring parameters such as pressure, borehole temperature, etc., as well as the azimuthal orientation of the meter 50, the torque applied to the runner 24, and the load applied to the hanger. for a hidden casing string running tool 24. The measured data can be transmitted to the surface by telemetry via a mud pulse communication channel using a pulse generator 70 (see Fig. 4) included in the measuring device 50. This pulse generator 70 can be used to generate negative pulses pressure in the fluid in the working string 30, which transmits impulses to the surface. However, the pulse generator 70 does not restrict the flow of fluids in the through-hole 52 of the meter 50 for generating mud pulse telemetry. Pulse generator 70 may selectively discharge fluid from workstring 30 into annulus 32 to generate negative pulses. Pulse generator 70 may include a receiver 104 and a transmitter 106, respectively, for receiving and transmitting telemetry data. Transmitter 106 may be disabled at desired times (e.g., when the workstring is lowered into and / or pulled out of the wellbore) to reduce the power consumed by meter 50. It should also be understood that various other telemetry devices 102 may be used to transmitting data to a surface controller such as an acoustic telemetry device, an electromagnetic telemetry device, an electrical signal telemetry device, an optical telemetry device, etc. These types of telemetry devices are well known in the art and will not be discussed further. However, it should be understood that none of these telemetry devices obstructs the through hole 52 and otherwise reduces the inner diameter ID1 of the through hole 52 in the meter 50.

[0023] After the liner 28 is placed in the wellbore 12, the liner hanger 21 can be installed by expanding one or more packers 20 to bring them into contact with the inner surface of the casing 34 and / or expanding the wedges. 22 to engage the inner surface. There are many ways to install the liner hanger 21 and / or release the running tool 24 from the liner casing 28 after the liner casing 28 has been set. Some examples of installing the liner hanger 21 can be by rotating the running tool 24 with the working string. 30, hydraulically activating the runner 24 by control lines and / or dropping the ball 48. One of the advantages of the currently used gauge 50 is that the through hole 52 of the device allows the hydraulics of the runner 24 to be activated by dropping the ball 48 through the work string 30. through the measuring device 50 to contact the ball seat 42 in the trigger 24. The hydraulics of the trigger 24 can be operated when the ball 48 enters the ball seat 42 to manipulate the pressure drop across the trigger 24. This pressure manipulation can be used to activate the liner casing hanger 21 by adjusting the operation of the running tool 24. In addition, the pressure manipulation (s) applied to the running tool 24 (as well as the workstring manipulation 30 applied to the running tool 24), can be used to generate a sequence that releases the running tool 24 from the liner casing 28. Manipulations with the workstring 30 can include compression (applied load), stress (removed load) and / or torque to create a sequence that activates the running tool 24.

[0024] When the liner hanger 21 is installed, it may be desirable to verify the integrity of the liner hanger 21 by applying a load to the liner casing 28. A load on the liner casing 28 can be applied by applying compression to the work string 30, which can be transferred via running tool 24 to the liner 28. If a predetermined load can be applied to the liner 28 without disrupting the function of the liner, then the liner 21 can be considered properly installed. The amount of load applied to the liner casing 28 can be determined by strain gauges 58, which can be located in recesses 61 on the outer surface 67 of the measuring device 50. When compression of the working string 30 is applied, the measuring device 50 can measure the compression experienced by the device 50, and determine the amount of load (or force) applied to the liner 28 and thus to the hanger 21 for the liner. The measured data can then be transmitted to surface controller 80 for evaluation.

[0025] Load cells 58 may be disposed circumferentially around the outer surface of meter 50 at two or more positions that are equidistant from each other. For example, in FIG. 2 and 3, three sensors 58 are shown positioned at angles "0", "120" and "240" degrees around the circumference of housing 66 (however, only one of the sensors 58 is shown). Strain gages 58 may provide compression, stress and / or torque measurements, thereby detecting the load, stress, and / or torque applied to tool 24. Strain gages 58 may be 3-axis strain gauges that can detect stress in a triaxial orthogonal coordinate system devices 50.

[0026] The measured data can be transmitted to the surface controller 80 via mud pulse telemetry. When measured data is received at the surface, decisions can be made such as releasing the running tool 24 and removing the workstring 30 from the wellbore 12 along with the measuring device 50. In addition, if the measured data indicates that the liner 21 is not installed properly, then corrective action can be taken to repair and / or rebuild it. The strain gauges 58 can provide visibility of completion operations while securing the completion string 100 to the casing in the wellbore 12. Completion tool 100 may be at least one of a countersunk casing 28, a liner 21, a bridge plug 90, a fracture plug 90, a whipstock 90, a packer 20, a sand screen, a milling tool, a fishing tool , a diverter (for example, to deflect a tubing string, downhole tool, etc. into a lateral wellbore), a completion device (for example, for hydraulic fracturing, diversion, etc.), an anchor device, etc. Securing the completion tool 100 to the casing 34 (or other tubing in the wellbore) may involve manipulating the workstring 30 to load the completion tool 100 through the measuring tool 50, the measuring tool measuring voltage supplied with the completion tool 100.

[0027] The measuring device 50 may include a hollow body 66, connection heads 53, 54, recesses 60, 61, 62 on the outer surface 67 of the body 66 with a plurality of sensors 64, 68 installed in the recesses 60, 62 and strain gauges 58 installed in the recesses 61. The internal flow passage may be a single through-hole 52 having a substantially constant inner diameter ID1. As used herein, the term “substantially constant diameter” refers to a diameter that can vary slightly along the length of the through hole, but the through hole maintains the specified diameter over most of the length.

[0028] Ball 48 is shown in three possible positions as it passes through gauge 50 into flush 24. Position 48a shows ball 48 passing through hole 52 in gauge 50. Ball 48 has an outer diameter OD1 that is less than the inner diameter ID1 through hole 52. Since there is no obstacle to the passage of the ball 48 through the device 50, the ball 48 is free to move towards the trigger 24. Position 48b shows the ball 48, which has entered the trigger 24, but before engaging with the seat 42 of the ball. The flow passage 38 may pass through the bleed tool 24 and may have an inner diameter ID2 that is also larger than the outer diameter OD1 of the ball 48. The ball 48 can move until it lands in the seat 42 of a ball whose inner diameter ID3 is less than the outer diameter OD1 of ball 48. The presence of ball 48 in ball seat 42 significantly restricts fluid flow through the run tool 24, and allows the controller to manipulate the pressure on tool 24, which can be used to set up a hanger 21 for a casing string (for example, setting a packer 20 and wedges 22). Pressure manipulation on tool 24 can also be used to release tool 24 from the liner casing 28.

[0029] FIG. 4 illustrates a perspective view of device 50 with various elements secured in recesses 60, 61, 62 in housing 66 of device 50. Hydraulic pulse generator 70, electrical connections 72, communication units 74, electronic equipment 76, sensors 64, 68, and strain gauges 58 may be located, as shown, in recesses on the outer surface 67 of housing 66. An enlarged portion of housing 66 of device 50 allows these components to be installed in device 50 without obstructing a through hole 52 that extends through device 50.

[0030] Thus, a measuring device 50 is provided for measuring the stress in the workstring 30 during well completion operations. Meter 50 may include a housing 66 with a plurality of recesses 60, 61, 62 on the outer surface 67 of housing 66, and strain gauges 58 that can detect compression, stress, and / or torque of housing 66 when strain gauges can be located in at least two of a plurality of recesses 61 and when these recesses 61 are circumferentially spaced equidistant from each other around the circumference of the housing 66. The measuring device 50 may comprise a hydraulic pulse generator 70 (or other telemetry devices such as an acoustic telemetry device, an electromagnetic telemetry device, a telemetry device with using an electrical signal and an optical telemetry device), which can be configured to transmit data received from the strain gauges 58 to the surface controller 80 by telemetry via the hydraulic impulse communication channel (or other telemetry channels), while the hydraulics A single pulse generator 70 is located in another one of a plurality of recesses 60, 62. As indicated above, the pulse generator 70 may include a receiver 104 and a transmitter 106, respectively, for receiving and transmitting telemetry data. Transmitter 106 may be disabled at required times (eg, when the workstring is run into and / or removed from wellbore 12, during extended periods of inactivity, etc.) to reduce the power consumed by meter 50. Pulse generator 70 may also represent other telemetry devices 102 as discussed above. A through hole 52 having a substantially constant inner diameter ID1 may extend through the housing 66 of the meter 50.

[0031] In any of the foregoing embodiments, the method may include any of the following elements, alone or in combination with one another.

[0032] The body 66 may have a threaded connection 53, 54 at each end of the device 50. The load cells 58 may be located in at least three of a plurality of recesses 61, with at least three recesses 61 being spaced circumferentially at an equal distance from each other along the circumference of the housing 66. Pressure and temperature sensors 64, 68 may be located in other recesses 60, 62 of the plurality of recesses 60, 61, 62 and feed the measured data to a hydraulic pulse generator 70 (or other telemetry device) that is configured to transmit measured pressure and temperature data to surface controller 80. Bore 52 may be configured to pass ball 48 through measuring device 50 and deliver ball 48 to downhole tools 24 located deeper in wellbore 12 than measuring device 50 to control these downhole tools 24.

[0033] A method is provided for installing a completion tool 100 in a wellbore 12, which may include the steps of connecting the completion tool 100 to a running tool 24, connecting a running tool 24 to a measuring device 50, connecting a measuring device 50 to a work string 30, and displacement of the working string 30, thereby placing the completion tool 100 at the desired location in the wellbore 12.

[0034] The operations may also include commanding the running tool 24 to set the completion tool 100, thereby securing the completion tool 100 to the casing 34 in the wellbore 12, manipulating the work string 30 thereby causing compression or stress, and / or rotating in the workstring 30 and applying stress to the running tool 24, measuring, by the measuring device 50, the force applied to the running tool 24, and determining that the force applied to the completion tool 100 exceeds a predetermined value, thereby indicating that the completion tool 100 is properly installed.

[0035] In any of the foregoing embodiments, the method may include any of the following elements, alone or in combination with each other.

[0036] Operations may also include measuring with sensors 64, 68 pressure and / or temperature downhole and transmitting the measured pressure and / or temperature data to surface controller 80 using hydraulic pulse generator 70 (or other telemetry device) in measuring device 50 The completion tool 100 may be at least one of a liner 28, a liner 21, a bridge plug 90, a fracture plug 90, a whipstock 90, a packer 20, a sand screen, a milling tool, a fishing tool , diverter, well completion device, anchor device, etc.

[0037] Operations may also include sensors 58 measuring compression or stress and / or torque in measuring device 50 and transmitting measured compression or stress and / or torque data to surface controller 80 via telemetry device 70 included in measuring device 50 and the telemetry device 70 may be a hydraulic pulse generator 70, an acoustic telemetry device, an electromagnetic telemetry device, an electrical signal telemetry device, or an optical telemetry device.

[0038] The operations may also include moving the ball 48 through the workstring 30 to engage the ball seat 42 in the running tool 24, whereby engaging the ball 48 with the ball seat 42 can instruct the running tool 24 to set the completion tool 100 and / or further command the running tool 24 to release the completion tool 100 from the running tool 24. The engagement of the ball 48 in conjunction with manipulation of the work string 30 can be used to command the running tool 24 to release the completion tool 100 from the running tool 24. Manipulation with the working string 30 can include the application of compression or stress to the working string 30, as well as the rotation of the working string 30.

[0039] The operations may also include moving the ball 48 through the through hole 52 of the meter 50 until it engages with the ball seat 42 in the trigger 24.

[0040] Another method is provided for installing a completion tool 100 in a wellbore 12, which may include the steps of connecting the completion tool to a running tool, connecting a running tool to a measuring device, connecting a measuring device to a working string, displacing a working string, thereby positioning a completion tool at a desired location in the wellbore during displacement, the meter pulse generator being configured with a reduced power configuration that consumes less power than a full pulse generator configuration, and reconfiguring the pulse generator to achieve the configuration full power when a predetermined condition occurs.

[0041] In any of the foregoing embodiments, the method may include any of the following elements, alone or in combination with each other.

[0042] The operations may also include commanding the running tool to set the completion tool, thereby securing the completion tool to the casing 34 (or other tubing) in the wellbore 12, manipulating the work string 30 thereby creating a stress in the working string 30 and creating a force applied to the running tool 24, measuring through the measuring device 50 the force applied to the running tool 24; and determining that the force applied to the completion tool 100 exceeds a predetermined amount, thereby indicating that the completion tool 100 is properly installed.

[0043] The pulse generator 70 may include a receiver 104 and a transmitter 106 in a reduced power configuration in which the receiver 104 is turned on to receive telemetry data and the transmitter 106 is turned off to prevent transmission of telemetry data. This can save energy since a portion of meter 50 can be turned off or at least put into a "sleep" mode that minimizes power consumption. This can be useful when the battery is the power source for the measuring tool 50 and the wellbore 12 is several hundred meters (thousand feet) deep. The time taken to move the measuring device 50 to the desired position in the wellbore 12 can be several hours and / or days. Therefore, the reduced power configuration can extend the battery life.

[0044] The pulse generator 70 may include a receiver 104 and a transmitter 106, and the full power configuration may be when receiver 104 is turned on to receive telemetry data and transmitter 106 is turned on to transmit telemetry data.

[0045] The predetermined condition may include a condition when completion tool 100 is located at a desired location or when a measurement tool detects a predetermined voltage, pressure, and / or temperature threshold during movement of completion tool 100 to a desired location in wellbore 12 wells.

[0046] The operations may also include reconfiguring the pulse generator 70 to achieve a reduced power configuration by issuing commands from the surface to the measurement device 50. This may be, for example, when the measurement tool 50 is removed from the wellbore 12, a long period is required. time between measurements or for any other reason to conserve the energy consumption of the measuring tool 50.

[0047] While various embodiments of the invention have been shown and described, the invention is not limited to such embodiments, and it will be understood that it includes all modifications and variations that would be obvious to one skilled in the art. Therefore, it should be understood that this disclosure is not intended to be limited to the specific forms disclosed; rather, the object is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the invention as defined in the appended claims.

Claims (46)

1. A measuring device for measuring stress in a working string during completion operations when attaching a completion tool in a wellbore, comprising: a body with a plurality of recesses on the outer surface of the body; strain gauges that detect casing compression, stress and torque applied to the completion tool during running string manipulation, wherein the strain gauges are located in at least two of the plurality of recesses and the at least two recesses are located circumferentially on equal distance from each other around the circumference of the body; a hydraulic pulse generator, which is configured to transmit data received from the strain gauges to the surface controller using telemetry via a hydraulic pulse communication channel, while the hydraulic pulse generator is located in another one of the plurality of recesses; and a through hole that extends through the body and has a substantially constant inner diameter. 2. The device according to claim. 1, characterized in that the strain gauges are located in at least three of the plurality of recesses, and the said at least three recesses are located circumferentially at the same distance from each other around the circumference of the housing. 3. The device according to claim 1, further comprising pressure and temperature sensors located in other recesses of the plurality of recesses, the pressure and temperature sensors supply the measured data to a hydraulic pulse generator, which is configured to transmit pressure and temperature measurement data to the surface controller. 4. A method for installing a completion tool in a wellbore, including: connecting the completion tool to the running tool; connection of the running tool with the measuring device made according to claim 1; connecting the measuring device to the working string; moving the working string, thereby placing the completion tool at the desired location in the wellbore; commanding the running tool to install the completion tool, thereby securing the completion tool to the casing in the wellbore; manipulating the working string, which includes applying compression, stress and torque to the working string during running, thereby creating stress in the working string and creating a force applied to the running tool; measurement with sensors of compression, stress and torque in the measuring device for subsequent determination on their basis of the force applied to the trigger; transmitting the measured compression, stress and torque data to the surface controller via a telemetry device included in the measuring device; and determining that the force applied to the completion tool exceeds a predetermined amount, thereby indicating that the completion tool has been properly installed. 5. The method of claim 4, further comprising measuring downhole pressure and / or temperature with sensors and transmitting the measured pressure and / or temperature data to a surface controller using a hydraulic pulse generator in the meter. 6. The method according to claim 4, characterized in that the tool for completing the well is selected from the group consisting of a countersunk casing, a hanger for a countersunk casing, a bridge plug, a hydraulic fracturing plug, a whipstock, a packer, a sand screen, a milling cutter tool, fishing tool, diverter, completion device and anchor device. 7. The method according to claim 4, characterized in that the telemetry device is selected from the group consisting of: a hydraulic pulse generator, an acoustic telemetry device, an electromagnetic telemetry device, a telemetry device using an electrical signal and an optical telemetry device. 8. The method according to claim 4, wherein the command additionally comprises moving the ball through the working string to engage with the ball seat in the running tool, whereby engaging the ball with the ball seat instructs the running tool to install a completion tool, in this case, the ball engagement additionally instructs the running tool to release the completion tool from the running tool, wherein the ball engagement in interaction with the manipulation with the working string gives the command to the running tool to release the completion tool from the running tool. 9. A method for assessing the integrity of a hanger for a blind casing installed in a casing in a wellbore, including: connecting the countersunk casing to the running tool, the countersunk casing comprising a hanger for the countersunk casing; connection of the running tool with the measuring device made according to claim 1; connecting the measuring device to the working string; moving the working string, thereby placing the liner hanger at the desired location in the casing; commanding the running tool to install the liner casing hanger, thereby securing the liner casing to the casing; increasing the load applied to the running tool by running the working string, which compresses the working string and creates a load applied to the running tool; measurement using sensors of compression, stress and torque in the measuring device for subsequent determination on their basis of the load applied to the running tool; transmitting the measured compression, stress and torque data to the surface controller via a telemetry device included in the measuring device; and determining that the load applied to the running tool exceeds a predetermined amount, thereby indicating that the liner hanger is properly installed. 10. The method according to claim 9, characterized in that the telemetry device is selected from the group consisting of: a hydraulic pulse generator, an acoustic telemetry device, an electromagnetic telemetry device, a telemetry device using an electrical signal and an optical telemetry device. 11. A method of installing a tool for completing a well in a wellbore, including: connecting the completion tool to the running tool; connection of the running tool with the measuring device made according to claim 1; connecting the measuring device to the working string; moving the working string, thereby placing the completion tool at the desired location in the wellbore; during travel, the meter pulse generator is configured to a reduced power configuration that consumes less power than a full pulse generator configuration; and reconfiguring the pulse generator to achieve full power configuration when a predetermined condition occurs; commanding the running tool to install the completion tool, thereby securing the completion tool to the casing in the wellbore; manipulating the working string, which includes applying compression, stress and torque to the working string during running, thereby creating stress in the working string and creating a force applied to the running tool; measurement with sensors of compression, stress and torque in the measuring device for subsequent determination on their basis of the force applied to the trigger; and determining that the force applied to the completion tool exceeds a predetermined amount, thereby indicating that the completion tool has been properly installed.

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