Untitled record

full description

invention background

This application enjoys a right of precedence based on US Application No. 255553/32, filed on January 35, 3533, which is fully incorporated by reference.

During drilling operations, sensors were used.

5 Mostly for measuring the different forces exerted on the drill string. Examples of forces

weight-on- bending forces Exemplary forces

bit on the different parts of the drill string. These forces may affect the dynamic behavior of the drill string and, if not monitored and controlled, may result in damage to downhole components or compromised operation.

35 operation These measurements give information that can be used, for example, to measure drilling parameters or monitor downhole conditions.

To measure the measurement of these forces, strain gauges can be used to measure strain at different locations of the drill string. conditions

35 The various considerations that must be taken into account when forming these strain gauges, such as the temperature sensitivity of gauges and any adhesives or other means used to assemble the gauges, in addition to the ease of manufacture, manufacture and installation of components that include strain gauges.

.strain gauges

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General description of the invention

The apparatus for measuring strain on a downhole carrier includes: Sensitive body

On fixedly mounted shaper, strain sensitive chassis

bearing surface; At least one strain gauge comprising at least one thin 5 film and a conductor applied to the surface of the chassis.

The strain sensing apparatus includes: a series of drill pipes shaped to be placed in a borehole in an earth formation; A strain-sensitive structure in a way that is installed in a fixed manner on the surface of the drill string, the structure is made of the same material as the drill string and is shaped to be subject to strain commensurate with the strain on the holder at the location

35 the structure; and at least one strain gauge comprising at least a conductive film placed on the surface of the structure.

The method of fabricating a strain gauge sensor on a well holder includes; Placing a thin layer of electrically insulating material on the structure, the structure is made of the material from which the bearing is primarily made and shaped to be subject to a strain proportional to the strain on the bearing

35 at the site of the structure; Apply a thin film electrical conductor to the thin film insulating layer or mount the structure firmly on the surface of the bearing.

Brief explanation of the drawings

35

Subject matter considered to be an invention, is specifically described

r and demands to protect it in a way

Outstanding in protections at the end of the profile. Previous features and other features and features of the invention

It is clear from the detailed description taken jointly with the attached drawings, where similar elements are numbered with similar numbers, in which:-

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Figure 3 is an example embodiment of a drilling system that includes a series of drill pipes placed in the drilling hole of an earth component.

Figure 3 is a perspective view of a portion of the drill string of Figure 3, including one or more sensor assemblies.

5 Figure 2 is a side view of the sensor assembly example from Figure 3.

Figure 4 is a top view of the Figure 4 sensor assembly.

Figure 5 is a sequence of events map showing an example method for measuring downhole parameters.

Detailed description:

35 Referring to Figure 3, an exemplary embodiment of a 35 downhole drilling system is shown in a borehole 33. A series of drill pipes 34 inserted into a borehole 33, which penetrates at least one earth component 31. Although the borehole 33 is shown in Figure 3 Being of a constant diameter, the drilling hole is unlimited. For example, the drilling hole 33 may be of varying diameter and/or direction

35 Variing direction variable (example: azimuth and inclination). 34 drill-pipe series eg made of pipe or multiple pipe sections. System 35 system and/or 34 drill-pipe series includes drill set 31. Various measuring tools measurement tools can also be incorporated into System 35 to influence measurement regimes such as wireline measurement applications.

35 measurement applications or logging-while-drilling (LWD) applications.

The 31 drill set, which may be configured as a BHA (bottomhole assembly), includes a 34 drill bit by means of various drill set components. 31 . drilling set

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Formed to move inside the 33 drilling rig of the 33 drilling rig. The drilling set also includes various components for structural and operational support of the 35 drill bit, such as a 34 drill bit body functionally connected to the 31 cutters, a drilling motor (also called a mud 5 motor) and a stabilizer reamer or reamer (.

The 31 processing unit is in operational contact with the 31 drilling group and may be located for example at a surface location, subsea location and/or a surface location on a marine well platform or marine craft. The handling unit 31 can also be integrated with the 34 35 drill string or the 31 drill set or placed elsewhere in the well upon request. Processing Unit 31 May

It constitutes functions such as monitoring controlling drilling group 31, transmitting and receiving data, and monitoring drilling group 31 and drilling rig chain 34. The processing unit 31, in one embodiment includes the processor 25, a data storage device (or data storage device) computer-readable 35 23 medium for storing, storing data, models and/or computer programs

computer programs 24 software.

System 35 also includes one or more strain sensor 21 assemblies to measure the forces experienced by the drill string while in the well and/or during operation. Each 21 sensor assembly includes at least one strain gauge 21 35 structure-mounted 45. One or more strain gauges 21 customized structure compound via sputtering or thin film deposition technique. The hull 45 is attached in a fixed manner to or mounted on the surface of the drill string 34, and is shaped to be subject to strain proportional to the strain on the drill string 34 and/or the drill string 31 at a location on the hull 45. As described therein, “hull” denotes any A support mount that can be mounted on a 35 gauge strain and in turn can be mounted on the surface of the drill string. structure, in one embodiment,

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A solid piece of material (example: steel) made of the same surface material and experiencing strain proportional to strain on the drill string, eg, breath or strain proportional to strain on the surface of the tubing string, eg, the material used to form the hull have the same coefficient or at least essentially the same coefficient of expansion

5 Like the drill pipe string material. Expansion coefficients may not be exactly the same as the chassis material's coefficient of expansion, which is on the order of the string material coefficient, for example: the tubes and the chassis experience at least essentially the same strain. The body shape 45 is unlimited, which may have any thickness or shape that may be used to mount the gauge and which may send and/or amplify the strain on a string of tubes.

35 drilling.

The strain gauge 21 sends signals to the processor in the form of eg voltage changes to a desired location. For example, strain gauges 21 are coupled to a downhole electronics unit 43 that may receive signals from strain gauges 21 and send the data to a processing system such as a unit

35 Processing 31. Signals and data can be transmitted by any suitable device or transmission system, for example: 44 cable. Other techniques used in transmitting signals and data include electric and/or fiber optic connections, wired pipe, mud pulse, electromagnetic telemetry and acoustic telemetry.

35 Processing unit 31 constitutes for analysis and/or transmission of data to the user or other site for analysis. This analysis includes an estimation of well parameters such as weight-on-bit (WOB), torque-on-bit (TOB) forces and torque-on-bit forces on portions of the 34 series drill-pipe portions or bending forces on BOB. bit). Parametric measurements such as torque and bending can also be used

35 To estimate other parameters such as direction or deviation of drill string deviation and deformation

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unwanted deformation such as buckling. Although the embeddings were developed jointly with the drilling and pipeline chain processes, which include logging-while-drilling (LWD) processes, they are unlimited. It can be used with any component, and it includes 5 downhole components such as wireline tools that suffer from stress.

Referring to Figure 3, embodiments of the sensor assembly 21 include one or more in terms of each strain gauge 45 attached in a fixed manner or mounted to the surface 44 drill pipe segment 34. This may be any surface and includes the exterior or interior of the drill pipe segment, 34 bit body and others. The frame 45 shall be installed on the surface 44 by any suitable means, such as by adhesive, welding, mechanical fastening.

mechanical securing or brazing such as bolting or screwing with pipe chain.

As shown in Figure 3, the 21 measurement assembly shows the different configurations that can be used to measure the strain on the 34 drill string.

35 orientations All 21 emotion scales are simply examples, where the emotion scale can be set up or oriented in any suitable fashion if required. Also, the number of strain gauges 21 in addition to the number of strain gauges 21 placed into each 45 frame is unlimited.

In this example, the 34 drill string defines the central longitudinal

41 axis, which is called "drill string axis" or "35 string axis". Each strain gauge 21 also specifies the “strain . axis.”

gauge axis” or “41” gauge axis that is proportional to the direction of sensitivity of the conductors for which it is measured changes changes in resistance. For the type 1 strain gauges shown therein, the axis of the strain gauge 41 is proportional to the direction of the rectangular conductors and also the direction of greatest sensitivity Examples of strain scale shapes are shown in Figure 3. For example, one or more of the 21 scales is shaped such that the axis of the scale is 41.

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It is essentially parallel to the axis of the tube chain 41, to measure the axial forces that can be used to estimate parameters such as WOB. Example: In another example, one or more of the scales 21 is oriented so that the axis of the scale 41 is at least essentially parallel to allow an estimate of bending forces. Also in another example, one or more of the 21 scales can be oriented about 45 degrees

5 For the pipe chain axis 41 to measure the torsional strain that can be used to estimate the torque on the parts of the pipe chain (eg TOB). It is noted that multiple assemblies and/or strain gauges with different directions can be connected in practice.

For example as part of a single assembly or bridge circuit. In an embodiment, one or more strain gauges may be installed such that the 35 strain gauge axis is positioned along one of the ideal bending line of the pipeline.

In one embodiment, one or more strain gauges 21 electrically connected as part of a bridge circuit, such as a Wheatstone bridge. Examples of such circuits include quarter bridge (includes one gauge), half bridge (includes two gauges) and full bridge (includes four gauges). 45, and may be electrically connected to form a complete arch.In other embodiments, an entire arch may be formed on a single frame 45.

Figure 2 illustrates component layers 21 strain gauge embodiments. In this embodiment, 21 strain gauge is a thin film or splattered strain measure. "Thin layer" generally refers to one or more layers of a substance having an average density of parts of a nanometer to

35 Several micrometres. The strain gauges 21 can be configured by different precipitation processes. One example process is the spray application technique, which includes placing an insulating layer 55 on the structure 45, applying and/or minimizing a conductive film 53 over an insulating layer 55 and optionally placing or covering the conductor 53 with a protective layer 54. The protective layer 54 may It is for example a polymer or epoxy material, a metallic material

35 metallic material or any other suitable material formed to withstand the heat present in the well environment.

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The wires of the 51 Gauge leads are connected to the ends of the connector. For example, insulating layer 55 is sprayed onto the surface of the chassis 21, and conductor 53 is formed by placing a thin layer of a resistive alloy or metal and etching (eg laser etching) a layer inside balanced resistors. A conductive film 53 and/or an insulating layer 55 includes spraying, evaporation, pulsed laser laying, chemical vapor deposition, and others.

In this embodiment, at least an insulating layer 55 and a conductive layer 53 are applied as thin film layers. The insulating layer may be any suitable, and includes dielectric materials such as plastics or ceramics. Examples of insulating 35 materials include polyimides or epoxies. conductive material

53 Conductive materials may be any conductive materials and include conductive metals such as copper and copper alloys (eg CopeL), platinum and platinum alloys, nickel, isoelastic alloys, and others.

35 Figure 4 shows an example set of 21 comprising a single strain gauge 21 placed on a frame 45. In this example, the frame 45 has dimensions of about 35 mm in length, and between 3-35 mm in thickness. The strain gauge 21 is a thin film laid with dimensions of about 4 mm x 2 mm. These dimensions are simply examples and are unlimited. The hull 45 may have any suitable space sufficient to support one or more strain gauges on it. In one embodiment, the area of ​​the structure is small to have 35 the smallest area required to support the strain gauge 21 and need wiring for leads.

Referring to Figure 5, an example method 15 for measuring well parameters is shown. Method 15 includes one or more of the 14-13 stages. In one embodiment, method 15 involves performing all stages 13-14 in the order described. However, some stages may be omitted, stages may be added, or the order of stages may change.

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In the first stage 13, one or more groups of sensor 21 assemblies are mounted on the surface of the drill string 34. Each group is installed eg welding, by mechanical means or an adhesion such as a threaded connection. Group 21 may be mounted directly on the surface and/or in a 5 bore recess or other form component on the 34 drill string. In one embodiment, Group 21 is fitted with a protective component such as a metal plate covering the assembly to protect against well conditions. Each group has 21 orientations as required to measure the desired type of emotion.

In the second stage 13, the tube chain 34 and the group or groups 21 are placed in the well eg during drilling or the LWD process. 34 Pipe string may be configured as any desired type such as 35 gauge tubing string or completion string.

In a third stage 12, the strain on a string of piping 34 during a drilling or LWD (or other required process) operation is measured by sending an electrical signal to a strain gauge 21 and measuring the change in conductor resistance 53. In an embodiment, group 21 includes one or more gauges Transmission 21 Connected to a Wheatstone bridge circuit Transmission and detection 35 detection may be made for example by the 43 electronics unit and/or the processing unit 31.

In the fourteenth stage, the change in resistance (example: indicated by the receiver voltage change) is analyzed by example: processing unit 31 to determine the strain on the pipeline 34. This strain information is also analyzed to measure the 35 different forces or by Well rams, such as WOB, compressive forces, bending forces and torques.

The systems and methods described in it offer different advantages over the techniques of prior art. For example, thin film strain gauges placed on the chassis as described allow for smaller sensor groups and larger thermal rates than previous art strain gauges. also,

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The shape and design of the structure is effective at transmitted strain and can also amplify the strain detected by the strain gauges placed on it.

5 In general, some of the instructions in it are reduced to the algorithm, which is stored on the media that is readable by the computer. The algorithm is used by the computer processing system and provides workers with the required output.

In supporting the instructions in it, various components of the analysis can be used, including digital and/or analog systems. For example, digital and/or analog systems 35 can be incorporated into the well electronics unit 43 or the processing unit 31. Systems may include components such as

Processor, analog-to-digital financier, digital-to-analog converter, storage media, memory, entry, exit, communications link (wired, wireless, blistered, optical or other), port of use, software, signal processors (digital or other) analog) and other components (such as resistors, capacitors, inductors, etc.) Note that these instructions may be used in combination with a set of computer executable instructions stored on computer-readable media including RAMS, ROMS memory, USB flash drives, removable storage devices, optical types CD-ROMS (optical) or magnetic 35 (disks, hard rotors) or any other type when implemented makes the computer use the method of the present invention. These instructions may provide equipment operation, monitoring, data collection, analysis and other functions that seem appropriate to the system designer, owner, user or other person, in addition to the functions described in this presentation.

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Note that different technologies or components may provide some necessary or beneficial features or functions. Accordingly, such functions and features as are required to support ancillary protections and their types are known to be duly included as part of the instructions therein and as part of the presented invention.

While describing the invention with reference to example embodiments, it is noted that various changes can be made5 and equivalents can be exchanged for elements thereof without departing from the scope of the invention. Also, many modifications can be used to use a particular device, state or material to instruct an invention without departing from its basic scope. Therefore, it should be noted that the invention is not limited to the particular embodiment presented as the best method for making this invention, but the invention may include all embodiments that fall within the scope of the ancillary protection elements.

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