FR3042214A1 - - Google Patents

Abstract

A system may include a downhole tool (116) transportable in a borehole (106) on a transport means (118), and a plurality of measuring devices (117) positioned at a distal end (119) of the downhole tool (116) for emitting wave energy (121) in an axial direction within the borehole (106). At least a portion of the wave energy (121) is reflected by one or more hazardous phenomena (122) of the borehole (106) and received by the plurality of measuring devices (117). The system further includes a data acquisition system communicatively coupled to the downhole tool (116) for receiving and processing reflected wave energy (121) and thereby identifying said one or more hazardous phenomena (122) of the drilling hole (106).

Description

SYSTEM FOR AVOIDING HAZARDOUS PHENOMENA DURING RECOVERY

WELL

BACKGROUND

Once a borehole has been drilled, it may be necessary to enter the borehole to carry out various operations, such as logging, completion, intervention, etc. Often this re-entry takes place long after the drilling and completion of the borehole. During this time, the conditions of the borehole may have changed. For example, the inside diameter of the borehole may not be as it was during the drilling and / or completion of the original. In other cases, there may be an accumulation of material deposits (paraffin, incrustations, etc.) on the walls of the borehole or the casing that covers the borehole. In still other cases, the casing may have been damaged or the borehole may contain various trapped objects (tools) that have inadvertently fallen into the well.

Due to these various obstructions in the borehole, bottom transport means, such as a train of articulated rods or concentric casing, may remain stuck or be damaged during a re-entry and through the hole drilling. Often, this results in a large amount of unproductive time trying to untie the means of transport, and this can cause damage to the means of transport and any tools related to the means of transport, loss of tools or even loss the use of the well. Even when the means of transport are not jammed, the speed at which the means of transport is lowered into or out of the well is often slow due to precautions due to unknown hazards or obstacles. The ability to enter and exit a well at optimum speed would significantly reduce the operating costs of the well.

BRIEF DESCRIPTION OF THE DRAWINGS

The following figures are included to illustrate certain aspects of the invention. present and are not to be considered as exclusive embodiments. The subject disclosed is subject to significant modifications, changes, combinations and equivalents in form and function, without departing from the scope of this disclosure.

[0004] Figure 1 illustrates a well system that can achieve or otherwise use one or more principles of this disclosure.

Figure 2A illustrates an enlarged perspective life of a distal end of the downhole tool in Figure 1 which shows a configuration of the plurality of measuring devices.

[0006] FIG. 2B illustrates another enlarged perspective view of the distal end of the downhole tool in FIG. 1 which represents another configuration of the plurality of measuring devices.

DETAILED DESCRIPTION

[0007] The present disclosure relates to a system that detects obstacles and hazards in the borehole in front of the drill string and communicates this information in real time so that the speed / speed with which the train is forced into the Well can be regulated to alleviate this problem.

Currently, bottom tools equipped with video cameras are lowered into the drill holes on a means of transport and used to detect any dangerous phenomenon (or obstruction) that may be in the borehole. However, in order to allow the video cameras of the downhole tool to represent the hazards of the borehole that may be in front of the downhole tool, it is necessary that there are clear fluids in the borehole . Instead, acoustic tools are sometimes used to detect potential hazards in the borehole. However, the existing acoustic tools represent the borehole only in the radial direction, and therefore must be moved past a point in the borehole to detect any dangerous phenomena present at that point. As a result, existing acoustic tools are not configured to "scan" in front of the bottom tool in the borehole.

The embodiments disclosed herein help to better identify the borehole hazard present in the borehole and make better decisions about how to remove or cure the hazardous phenomena of the borehole. This reduces non-productive time during borehole operations due to downhole tools or conveyances stuck in the borehole due to unknown hazards or obstacles, reduces cost due to poor quality, and costs. incurred for lost tools. Embodiments disclosed herein also allow for optimal speed of movement in and out of the borehole without the risk of striking the borehole hazard present in the borehole.

Referring to Figure 1, it illustrates a well system 100 which can achieve or otherwise use one or more principles of this disclosure, according to one or more embodiments. As illustrated, the well system 100 may include a service drill 102 that is positioned at the surface 104 of the earth and extends over and around a borehole 106 that enters an underground formation 108. Service 102 may be a drilling rig, a completion apparatus, a repackaging apparatus, or the like. In some embodiments, the service borer 102 may be omitted and replaced by a standard surface wellhead completion device or facility, without departing from the scope of the disclosure. In addition, while the well system 100 is shown as a land operation, it will be understood that the principles of this disclosure could similarly be applied to any marine or underwater application where the service driller 102 may be a floating platform , a semi-submersible platform or an underground wellhead installation, as is generally known in the art.

The borehole 106 may be drilled into the subterranean formation 108 using any suitable drilling technique and may extend in a substantially vertical direction away from the surface 104 of the earth on a vertical well portion 110 At a certain point in the borehole 106, the vertical well portion 110 may deviate from the vertical relative to the earth surface 104 and pass to a substantially horizontal well portion 112. In some embodiments, the borehole 106 may be completed by cementing a tubing string 114 within the borehole 106 on all or a portion thereof. In other embodiments however, the casing string 114 may be omitted from all or part of the borehole 106 and the principles of this disclosure may also apply to an "open hole" environment. .

The system 100 may further include a downhole tool 116 which may be transported in the borehole 106 on a transport means 118 which extends from the service drill 102. In some embodiments, the transport means 118 may include a cable having one or more power lines and / or fiber optic waveguides. In at least one embodiment, the cable and the transport means 118 may comprise the same structure. However, in other embodiments, the transport means 118 and the cable may not be identical and the cable may rather be coupled to the transport means 118 and further be attached together therewith. but not used to lower the downhole tool 116 into the borehole 106. Suitable transport means 118 may in this case include a drill pipe, a concentric casing, a production column, a bottom pulling device, and the like.

In some embodiments, the transport means 118 (and / or the cable) may be in surface communication with a data processing unit 124 and may provide two-way communication in real time between the communication tool. Background 116 and data processing unit 124. Data processing unit 124 may include a signal processor 126 communicatively coupled to a computer readable storage medium 128 and storing program code executed by processor 126. The results of the processing may be displayed on a display 130. Examples of a computer-readable storage medium include non-transitory support, such as random access memory (RAM) devices, read-only memory (ROM) devices, optical devices (e.g. CDs or DVDs) and disk drives.

According to the present disclosure, the bottom tool 116 may comprise a set of measuring devices 117 located at the distal end. As used herein, the term "distal" refers to that portion of the component that is furthest from the wellhead. Each measuring device 117 may emit wave energy 121 into the borehole 106 to detect one or more hazardous phenomena of the borehole 122 present in the borehole 106. For purposes of this discussion, the hazards the borehole 122 may include any obstacle which may hinder the advancement of the downhole tool 117 or the conveyance 118 within the borehole 106. Examples of the hazardous phenomena of the borehole 122 include without restriction a tool lost in the borehole 106, a damaged casing 114, an accumulation of a substance (eg paraffin, incrustations, etc.) in the borehole 106, or any combination thereof.

Those skilled in the art will appreciate that although FIG. 1 shows the bottom tool 116 as being arranged and operating in the horizontal portion 112 of the borehole 106, the embodiments described herein apply equally well. for use in portions of the borehole 106 which are vertical, deflected or otherwise inclined.

FIG. 2A illustrates an enlarged perspective view of a distal end 119 of the bottom tool 116 of FIG. 1. As illustrated, the measuring devices 117 may be arranged in a desired configuration on a front face 115 from the bottom tool 116 to the distal end 119. In at least one embodiment, as illustrated, the measuring devices 117 may be angularly offset from one another on the end face 115 by spacing. equidistant. However, in other embodiments, the measuring devices 117 may be angularly offset from one another on the end face 115 by random spacing without leaving the field of the disclosure.

The measuring devices 117 may be arranged such that the wave energy 121 from each of the measuring devices 117 is emitted in a generally axial direction within the borehole 106 (or casing 114, figure 1). As the term is used herein, the axial direction refers to the direction that is substantially parallel to the longitudinal axis A of the borehole 106 and / or the bottom tool 116. However, the wave energy 121 emitted may have a range of axial angles cp, such as anything less than 90 ° with respect to the longitudinal axis A. As illustrated in FIG. 2A, the axial angle cp is defined between the direction of movement of the wave energy 121 and the longitudinal axis of borehole 106 and / or casing 114.

In one example, the wave energy 121 emitted by the measuring devices 117 may comprise acoustic wave energy and the measurement devices 117 may comprise acoustic measuring devices, each of which may comprise a wave generator. acoustic and acoustic sensor. The acoustic wave generator emits acoustic waves through the fluid present in the borehole 106. The acoustic waves can be reflected on the measuring devices 117 by the dangerous phenomena of the borehole 122.

In another example, the wave energy 121 may comprise pressure pulses and the measuring devices 117 may alternatively comprise pressure measuring devices, each of which comprises a pressure pulse generator and a pressure sensor. pressure. The pressure pulse generator transmits a pressure pulse through the fluid into the borehole 106, at least a portion of which may be reflected by the hazards of the borehole 122. The reflected pressure pulse can then be received by the pressure measuring devices.

In yet another example, the wave energy 121 may comprise radiant energy, such as visible light, gamma rays, radio waves, ultraviolet light, infrared radiation, and measuring devices 117. understand adequate devices to capture radiant energy. If, for example, the wave energy 121 comprises visible light, then the measuring devices 117 may comprise optical measuring devices, each of which may comprise a light pulse generator and an optical sensor. The light pulse generator emits pulses of light through the fluid and any light pulse reflected by one or more hazardous phenomena of the borehole 122 in the borehole 106 is received by the optical sensor.

In still other examples, the wave energy 121 may comprise electromagnetic waves (EM) and the measuring devices may comprise EM transceivers each comprising an EM source which emits EM waves and an EM receiver which receives EM waves reflected by the dangerous phenomena of the borehole 122.

It should be noted that the wave energy 121 is not limited to the examples mentioned herein and may include other types of wave energy without leaving the field of the presentation. It should also be noted that it is not necessary for all measuring devices 117 to capture the same parameter. For example, a measuring device 117 could pick up pressure waves, while another measuring device 117 on the same bottom tool 116 could pick up radiant energy waves.

The distance over which the wave energy 121 propagates in the borehole 106 can define a field of view 120 of the bottom tool 116. When the bottom tool 116 is transported to the bottom of the hole, the Hazardous phenomena of the borehole 122 which lie within the field of view 120 can be detected. The measuring devices 117 may be arranged such that the wave energy has the field of view 120 having a predetermined shape and extending over a predetermined axial distance L (for example about 5 to 10 feet) from the distal end. 119 of the bottom tool 116. For example as illustrated in Figure 2A, the field of view 120 is generally conical or frustoconical.

In one embodiment, the measuring devices 117 can transmit wave energy 121 having different frequencies. Since different frequencies are absorbed or reflected differently by different materials, by choosing frequencies with different rates of absorption / reflection, one can determine the size, shape and material of the dangerous phenomena of the borehole 122. For example a Relatively harder material can reflect a relatively greater amount of frequencies compared to a relatively softer material. Therefore, the material hardness of the borehole 122 hazardous phenomena can be determined and would make it possible to differentiate between "hard" and "soft" borehole hazards (such as steels and paraffins). The frequencies that are received by the measuring devices 117 are communicated to the data processing unit 124 which can process the received frequencies to produce an image of the hazards of the borehole 122 which is displayed on the display 130.

In another embodiment, based on the time difference between the moment when the wave energy 121 has been transmitted by the measuring device 117 and the moment when the reflected wave energy 121 has been received by the device 117, the data processing unit 124 (FIG. 1) can determine a distance up to one or more dangerous phenomena from the borehole 122. Once the dimension, the shape and / or the material of the dangerous phenomena of the drilling hole 122 and a distance to the hazards of the borehole 122 have been determined, an operator can take corrective measures to remove or repair the dangerous phenomenon 122. The operator can control the measuring devices 117 by the intermediate of the data processing unit 124 to vary the frequencies transmitted to obtain a better picture of the dangerous phenomena of the borehole 122. This can ensure a better understanding of the size and shape of the hazards of the borehole 122, and / or better identify the material of the hazards of the borehole 122. The corrective measures can then be modified to remove the hazard phenomenon 122 more effective or guide a cleaning tool (or check the quality of cleaning).

FIG. 2B illustrates another enlarged perspective view of the distal end 119 of the bottom tool 116 of FIG. 1. FIG. 2B may be similar to FIG. 2A at certain points, and therefore, it will be best understood by referring to it where the same numbers denote the same components that are not yet described in detail. In the embodiment illustrated in FIG. 2B, the measuring devices 117 may be arranged around the outer periphery of the bottom tool 106 at the distal end 119 thereof. Again, the measuring devices 117 may be arranged such that the wave energy 121 from each of the measuring devices 117 is emitted in a generally axial direction. It should be noted that the configuration (or placement) of the measuring devices 117 on the downhole tool 116 in Figs. 2A and 2B is only exemplary and that any configuration of the measuring devices 117 which results in the Wave energy 121 is emitted in the direction axial direction falls within the scope of this disclosure.

Embodiments disclosed herein include: A. A system that includes a downhole tool that can be transported in a borehole on a transport means, a plurality of measuring devices positioned at a distal end of the downhole tool for emitting wave energy in an axial direction within the borehole, at least a portion of the wave energy being reflected by one or more hazardous phenomena of the borehole and received by the plurality of measurement devices, and a data acquisition system coupled in communication with the downhole tool for receiving and processing reflected wave energy and thereby identifying one or more hazardous phenomena of the borehole.

B. A method which comprises conveying a downhole tool into a borehole on a conveyance, emitting wave energy in an axial direction within the borehole using a plurality of measuring devices positioned at a distal end of the downhole tool, at least a portion of the wave energy being reflected by one or more hazardous phenomena of the borehole, receiving reflected wave energy using the plurality of measuring devices, receiving and processing the reflected wave energy with a data acquisition system coupled in communication with the downhole tool, and identifying one or more hazardous phenomena of the borehole by the data acquisition system based on reflected wave energy.

Each of Embodiments A and B may include one or more of the following additional elements in any combination: Element 1: The plurality of measuring devices is located on a front face of the downhole tool.

Element 2: the plurality of measuring devices is located around an outer periphery of the bottom tool at the distal end. Element 3: The wave energy emitted by the plurality of measurement devices has a field of view having a predetermined shape and extending a predetermined distance from the distal end of the downhole tool. Element 4: The data acquisition system processes reflected wave energy to determine at least one of a size, shape, and material of said one or more hazardous phenomena of the borehole. Element 5: the data acquisition system processes the reflected wave energy to determine a hardness of the material of said one or more hazardous phenomena of the borehole, and differentiates between two or more hazardous phenomena of the borehole on the base the hardness of the material of the two or more dangerous phenomena of the borehole. Element 6: the wave energy comprises at least one of acoustic waves, pressure pulses, electromagnetic waves and radiant energy. Element 7: The data acquisition system determines a distance from said one or more dangerous phenomena of the borehole relative to the downhole tool. Element 8: The data acquisition system processes the reflected wave energy to display an image of said one or more hazardous phenomena of the borehole.

Element 9: The emission of the wave energy includes generating a field of view having a predetermined shape and extending a predetermined distance from the bottom tool. Element 10 further comprising processing the reflected wave energy using the data acquisition system to determine at least one of a size, shape and material of said one or more hazardous phenomena of the borehole. Element 11: Treating reflected wave energy using the data acquisition system to determine a hardness of the material of said one or more hazardous phenomena of the borehole, and to differentiate between two or more hazardous phenomena of the borehole on the basis of the hardness of the material of the two or more dangerous phenomena of the borehole. Element 12: The emission of the wave energy comprises transmitting at least one of acoustic waves, pressure pulses, electromagnetic waves and radiant energy. Element 13 further comprising processing the reflected wave energy using the data acquisition system to determine a distance from said one or more hazardous phenomena of the borehole relative to the distal end of the background. Element 14 further comprising processing the reflected wave energy to display an image of said one or more hazardous phenomena of the borehole. Element 15 further comprising varying a frequency of the wave energy emitted by one or more measuring devices of the plurality of measuring devices to vary the image of said one or more hazardous phenomena of the borehole. Element 16 further comprising emitting the wave energy using the plurality of measuring devices located on a front face of the downhole tool at a distal end thereof. Element 17 further comprising emitting the wave energy using the plurality of measurement devices located around the periphery of the downhole tool at a distal end thereof.

By way of non-restrictive example, the combination examples applicable to A and B comprise: Element 4 with

Element 5; Element 10 with Element 11; and Element 14 with

Element 15.

Therefore, the systems and methods disclosed are well suited to achieve the stated objectives and benefits as well as those inherent therein. The particular embodiments disclosed above are purely exemplary, since the teachings of the present disclosure may be modified and put into practice in a different but equivalent manner, obvious to those skilled in the art benefiting from the present teachings. In addition, no restriction is contemplated with respect to the construction or design details shown herein, other than those described in the claims hereinafter. Therefore, it is obvious that the embodiments disclosed above may be changed, combined or modified, and all such variations are considered to fall within the scope of this disclosure. The systems and methods disclosed herein by way of example may be conveniently practiced in the absence of any element not specifically disclosed herein and / or any optional feature disclosed herein. While the compositions and methods are described by "comprising", "containing" or "comprising" various components or steps, the compositions and methods may also be "substantially compounded" or "compounds" of the various components and steps. All numbers and ranges disclosed above may vary to some extent. Whenever a range of numbers with a lower limit and an upper limit is disclosed, any number and range included falling into the range is specifically disclosed. In particular, it will be understood that each range of values (in the form "from about a to about b" or equivalently "from about a to b" or equivalently "from about ab") disclosed herein specifies each number. and range encompassed within the wider range of values. In addition, the terms in the claims have their ordinary meaning, ordinary, unless explicitly and clearly defined by the patentee. In addition, the undefined articles "a" or "an" as used in the claims are defined herein as meaning one or more of one of the elements they introduce. In the event of a conflict in the use of a word or term in this description and one or more patents or other documents which may be incorporated herein by reference, the definitions which are consistent with this description.

As used herein, the phrase "at least one of" preceding a series of elements, with the words "and" or "or" to separate the elements, modifies the list as a whole. rather than each element of the list (ie each element). The phrase "at least one of" means a meaning that includes at least one of one of the elements and / or at least one of any combination of elements and / or at least one of each of the elements. By way of example, the phrases "at least one of A, B and C" or "at least one of A, B or C" each refer to A only, B only or C only; any combination of A, B and C; and / or at least one of each of A, B and C.

The use of directional terms, such as above, below, above, below, up, down, left, right, upwell, downhole and the like are used in connection with the modes. exemplary embodiments as shown in the figures, the upward upward direction of the corresponding figure and the downward downward direction of the corresponding figure, the upward direction of the well toward the well surface and downhole direction towards the end of the well.

Claims (19)

A system (100) for detecting obstacles and / or hazards (122) in a borehole (106), comprising: a downhole tool (116) transportable in the borehole (106) on a means of transport (118); a plurality of measuring devices (117) positioned at a distal end (119) of the downhole tool (116) for emitting wave energy (121) in an axial direction within the borehole (106); ), at least a portion of the wave energy (121) being reflected by one or more hazards (122) of the borehole (106) and received by the plurality of measuring devices (117); and a data acquisition system communicatively coupled to the downhole tool (116) for receiving and processing reflected wave energy (121) and thereby identifying said one or more hazardous phenomena (122) of the borehole ( 106). The system (100) of claim 1, wherein the plurality of measuring devices (117) is located on a front face of the bottom tool (116). The system (100) of claim 1, wherein the plurality of measuring devices (117) is located about an outer periphery of the bottom tool (116) at the distal end (119). The system (100) according to claim 1, wherein the wave energy (121) emitted by the plurality of measuring devices (117) is emitted so as to have a field of view (120) having a predetermined shape and extending a predetermined distance from the distal end (119) of the bottom tool (116). The system (100) of claim 1, wherein the data acquisition system processes the reflected wave energy (121) to determine at least one of a size, shape, and material of said one or more hazardous phenomena. (122) of the borehole (106). The system (100) of claim 5, wherein the data acquisition system processes the reflected wave energy (121) to determine a hardness of the material of said one or more hazards (122) of the borehole (106). ), and differentiates between two or more hazards (122) of the borehole (106) based on the hardness of the material of the two or more hazards (122) of the borehole (106). The system (100) of claim 1, wherein the wave energy (121) comprises at least one of acoustic waves, pressure pulses, electromagnetic waves, and radiant energy. The system (100) of claim 1, wherein the data acquisition system determines a distance from said one or more hazards (122) of the borehole (106) relative to the downhole tool (116). . The system (100) of claim 1, wherein the data acquisition system processes the reflected wave energy (121) to display an image of said one or more hazardous phenomena (122) of the borehole (106). A method of detecting obstacles and / or hazards (122) in a borehole (106), comprising the steps of: transporting a downhole tool (116) into a borehole (106) on a means transportation (118); emitting wave energy (121) in an axial direction within the borehole (106) using a plurality of measuring devices (117) positioned at a distal end (119) of the downhole tool ( 116), at least a portion of the wave energy (121) being reflected by one or more hazards (122) of the borehole (106); receiving reflected wave energy (121) using the plurality of measuring devices (117); receiving and processing the reflected wave energy (121) with a data acquisition system communicatively coupled to the downhole tool (116); and identifying said one or more hazardous phenomena (122) of the borehole (106) with the data acquisition system based on reflected wave energy (121). The method of claim 10, wherein transmitting the wave energy (121) comprises generating a field of view (120) generated to have a predetermined shape and extending a predetermined distance by relative to the downhole tool (116). The method of claim 10, further comprising processing the reflected wave energy (121) using the data acquisition system to determine at least one of a size, shape and material of said one or a plurality of hazardous phenomena (122) of the borehole (106). The method of claim 12, further comprising the steps of: processing the reflected wave energy (121) using the data acquisition system to determine a hardness of the material of said one or more hazardous phenomena (122) of the drilling hole (106); and differentiating between two or more hazards (122) of the borehole (106) based on the hardness of the material of the two or more hazards (122) of the borehole (106). The method of claim 10, wherein the emission of the wave energy (121) comprises transmitting at least one of acoustic waves, pressure pulses, electromagnetic waves, and radiant energy. . The method of claim 10, further comprising processing the reflected wave energy (121) using the data acquisition system to determine a distance from said one or more hazardous phenomena (122) of the borehole ( 106) relative to the distal end (119) of the bottom tool (116). The method of claim 10, further comprising processing the reflected wave energy (121) to display an image of said one or more hazardous phenomena (122) of the borehole (106). The method of claim 16, further comprising varying a frequency of the wave energy (121) emitted by one or more measuring devices (117) of the plurality of measuring devices (117) to vary. image of said one or more hazardous phenomena (122) of the borehole (106). The method of claim 10, further comprising emitting the wave energy (121) using the plurality of measuring devices (117) located on a front face of the downhole tool (116) at a distal end (119) thereof. The method of claim 10, further comprising transmitting the wave energy (121) using the plurality of measurement devices (117) located around the periphery of the downhole tool (116) at a distance of distal end (119) thereof.