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    • 专利摘要:
    A system and method for performing a borehole operation, wherein the system may include a wrapped tubing string and an optical fiber cable disposed in the wrapped tubing string and wherein the fiber optic cable is constrained coupled to the wrapped tubing string. A method of performing a borehole operation may include disposing a tubing string wound in a borehole and wherein an optical fiber cable is constrainedly coupled to the wound tubing string, and measuring at least one property of the borehole with the fiber optic cable
    公开号:FR3073554A1
    申请号:FR1859858
    申请日:2018-10-25
    公开日:2019-05-17
    发明作者:Michel Joseph LeBlanc；Mark Elliott Willis；Andreas Ellmauthaler；Daniel Joseph QUINN；Philippe QUERO；Mikko Jaaskelainen；Alexis Garcia
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    SYSTEM AND METHOD FOR PROVIDING VERTICAL SEISMIC PROFILES IN DRILLING HOLES USING SOUND DISTRIBUTED SENSING ON DEPLOYED OPTICAL FIBER USING WOUND TUBING
    CONTEXT
    Drill holes drilled in underground formations can recover desirable fluids (eg, hydrocarbons) using a number of different techniques. During drilling operations, it can be beneficial for operators to know the type of formation since a downhole assembly crosses different formations. For example, currently after the completion of drilling operations, a cable system can be placed inside the wellbore and measurements can be taken, covering a specific depth range. A source of vibrations, placed on the surface, can be activated to launch acoustic waves in the formations below. A cable system can detect, record and measure acoustic waves as they pass through and / or are reflected through the formation. The processing of recorded acoustic waves can be used to produce an acoustic velocity profile for rock formations traversed by acoustic waves. An acoustic velocity profile can be used to identify rock formations or to measure various rock properties. Measuring the speed of acoustic waves can be repeated many times to form a vertical seismic profile.
    Examination of a vertical seismic profile may indicate to an operator that a wellbore operation may prove beneficial to the borehole for production. It is time consuming and expensive to remove the cable system, assemble the coiled tubing and arrange the coiled tubing in the borehole for subsequent operations in the borehole. In addition, it can be time consuming and expensive to disassemble the coiled tubing so a cable system can be mounted to determine the effects of work on the borehole. If the effects on the borehole are not satisfactory, even more time, money and effort will be required to dismantle the cable and repeat the process. Examples of common types of operations in which this can occur include drilling the borehole, cleaning, fracturing and / or acidification and lifting with nitrogen. A system and method capable of performing pacing operations and being capable of simultaneously recording measurements to produce a vertical seismic profile may prove beneficial.
    BRIEF DESCRIPTION OF THE DRAWINGS
    These drawings illustrate aspects of certain examples of the present invention, and should not be used to limit or define the invention.
    Figure 1 illustrates an example of a coiled tubing column; and
    Figure 2 illustrates an example of a processing operation in a borehole.
    DETAILED DESCRIPTION
    The present invention may generally relate to a system and method for collecting seismic data. In particular, the embodiments may relate to the collection of seismic data while the coiled tubing, equipped with an optical fiber, is in the borehole. Coiled tubing fitted with a fiber can enable many applications to be performed while the coiled tubing is disposed in the borehole, such as producing seismic products in boreholes using distributed acoustic detection.
    Figure 1 illustrates a coiled tubing system 100, which may include a coiled tubing column 102. In examples, the coiled tubing column 102 may be coupled to a downhole assembly (not shown) composed of various subassemblies and tools, such as a gamma ray detection tool, a casing location tool, or a pulse telemetry tool. The coiled tubing column 102 may be disposed around and / or removed from the coil 104 by a tubing injector 106 and injected into a borehole 108 through a packing 110 and a blowout preventer 112. This may allow the coiled tubing column 102 to pass through the borehole 108. As shown, a borehole 108 may be vertical. However, as described in more detail below, a borehole 108 can have a relatively large span and possibly rotate horizontally. In addition, directional drilling can result in a tortuous borehole 108 with many curvatures and many bends. The coiled tubing operations can be adapted to provide access to this borehole 108, taking into account that the deployment of cable tools in this borehole 108 may require a powered traction tool, which increases the cost and the weight of the instrument column and lengthens the duration of the operation.
    In examples, the coiled tubing column 102 can be a continuous length of steel, alloy steel, stainless steel, composite tubing or other suitable metallic or non-metallic material which can be flexible enough to be wound on a reel 104 for transportation, and the reel 104 itself can be located on a reel tubing truck for mobility reasons (not shown). Given the relative absence of seals, it may be advantageous to use a coiled tubing column 102 when pumping chemicals to the bottom of the hole.
    In the borehole 108, the coiled tubing column 102 may include a subassembly and one or more tools coupled to the coiled tubing column 102, which may constitute the downhole assembly. The subassembly can control the communication between the hole-mouth elements and the downhole elements, and can also control the communication between the downhole elements such as the one or more tools by providing a common clock, a power source, communication bus and the like. The tools may be sub-assemblies, or other sections of the coiled tubing column 102, which perform functions specific to a coiled tubing operation. For example, in a punching operation, the tools may include a punching tool comprising punches and the like. As another example, in milling operations, the tools may include a milling tool including a drill bit. Without limitation, coiled tubing applications can also be performed at sea.
    The tools arranged at the end of the coiled tubing column 102 can be controlled by the information processing system 114. In addition, the measurements taken and / or carried out by the tools can be transmitted to the information processing system 114. As illustrated, the information processing system 114 may include any instrument or set of instruments which can operate to calculate, estimate, classify, process, transmit, receive, retrieve, create, swap, store, display, highlight, detect, record, reproduce, process or use any form of information, intelligence or data for commercial, scientific, ordering or other purposes. For example, a personal computer, a network storage device, or any other suitable device may be an information processing system 114, and the size, shape, performance, functionality, and price thereof. these may vary. The information processing system 114 may include a central processing unit 116 (for example a microprocessor, a central processing unit, etc.) which can process the EM log data by executing software or instructions obtained from media computer readable non-transient local 118 (for example, optical discs, magnetic discs). Non-transient computer-readable media 118 may store software or instructions for the methods described herein. Non-transient computer-readable media 148 may include any instrument or set of instruments that can retain data and / or instructions for a period of time. The non-transient computer-readable media 118 may include, for example, storage media such as a direct access storage device (eg, a hard disk drive or a floppy drive), a sequential access storage device (for example a tape disc player), a compact disc, a CD-ROM, a DVD, a random access memory, a read-only memory, an electrically erasable and programmable read-only memory (EEPROM), and / or a flash memory; as well as communication media such as wires, optical fibers, microwaves, radio waves and other electromagnetic and / or optical media; and / or any combination of the above. The information processing system 114 can also include one (or more) input devices (120) (for example, a keyboard, a mouse, a touchpad, etc.) and one (or more) output devices (152) for example, a monitor, printer, etc.). The input device (s) 120 and the output device (s) 122 provide a user interface that allows an operator to interact with tools coupled to the coiled tubing column 102. For example, the information processing system 114 may allow an operator to select analysis options, view collected logging data, view analysis results and / or perform other tasks.
    In examples, a fiber optic cable 124 can be disposed inside the coiled tubing column 102. The fiber optic cable 124 can be used as a communication medium between the information processing system 114 and a tool disposed on the coiled tubing column 102, or can be used for detection, for example via distributed temperature detection ("DTS"). The fiber optic cable 124 may consist of one or more optical fibers, all of which may be a single-mode fiber, multimodal fibers, and / or a combination of multimodal fibers and single-mode fibers. In addition, the optical fiber cable can be integrated inside an electrically conductive cable in which the optical fibers and the electric cables can be grouped together. In examples, the electrical cables may include an electrical wire. Wires can be used to power downhole tools, transmit data to and from the surface, send commands to and from the surface, and / or be used for telemetry, and / or a combination of them. In examples, the fiber optic cable 124 can be used as a distributed acoustic detection ("DAS") tool, which can be used to produce a vertical seismic profile ("VSP"). To produce a VSP, acoustic waves propagating in a rock formation, which can be elastic waves, produce dynamic stresses in the rock formations, which can be recorded. These constraints can be routed to the fiber optic cable 124 disposed in the coiled tubing column 102.
    In examples, the fiber optic cable 124 can be forcedly coupled to the coiled tubing column 102, which can allow the transfer of forces to the fiber optic cable 124. Therefore, the stress experienced by the coiled tubing column 102 can be transferred to the fiber optic cable 124, which can be used to measure the stress. For example, a displacement of the surrounding rocks in formation 130 may affect the coiled tubing column 102, and in turn, displacement of the coiled tubing column 102 may produce stress in the fiber optic cable 124. Unless great care is taken to ensure uniformity of the stress coupling mechanism holding the fiber optic cable 124 to the coiled tubing column 102, the sensitivity of the fiber optic cable 124 to movement may vary along of hole 108. For example, at a location along the coiled tubing column 102, the fiber optic cable 124 can be hung inside the coiled tubing column 102 without being in contact with the walls of the column of coiled tubing 102. Thus, the stresses exerted on the column of coiled tubing 102 can only be transferred in part to the fiber optic cable 124. In examples, it is possible to establish an average of the stress measurements over the entire length of the optical fiber cable 124 delimited by the nearest locations where there is contact between the optical fiber cable 124 and a wall of a coiled tubing column 102 to determine the stress measurements. A similar problem may arise in the stress coupling between the borehole 108 and the coiled tubing column 102. To record a seismic signal with minimal noise, the borehole 108 may be in contact with the coiled tubing column 102 over at least part of the length of interest to produce a VSP profile. In addition, contact between the fiber optic cable 124 and the inner wall of the coiled tubing column 102 can also improve the detection, recording and measurement of seismic waves over at least a portion of the same length.
    To achieve proper stress coupling, the fiber optic cable 124 may include "an additional cable length" to ensure that the fiber optic cable 124 can be in physical communication within the coiled tubing column 102 at the as a result of the deformation caused by the axial force required to maintain the additional cable length in the coiled tubing column 102. In other words, the fiber optic cable 124 disposed in the coiled tubing column 102 may be longer than the coiled tubing column 102 so that there is an additional length of optical fiber cable 124 in the coiled tubing column 102. In examples, the optical fiber cable 124 may have a length greater than that of the coiled tubing 102 of at least 1%, 5%, 10% or more. In examples, stress coupling may also include welding the fiber optic cable 124 to the inside diameter of the coiled tubing column 102 during manufacture of the coiled tubing column 102. In addition, the fiber optic cable 124 may be magnetized and / or fixed to the coiled tubing column 102 through a mechanical device such as a hook, or an expansion tube (grid type) inside the coiled tubing column 102. It should be specified that the fiber optic cable 124 can be placed on the inside diameter and / or the outside diameter of the coiled tubing column 102. In examples, the internal diameter of the coiled tubing column 102 can provide protection for the cable 124 fiber optic during borehole operations.
    During operations, the coiled tubing column 102 may be disposed within the borehole 108 and may be in communication with the interior diameter of the borehole 108 and / or a cement casing of the borehole 108. In examples, a seismic source 126 can be used to produce seismic waves 128 which can pass through the formation 130 and can be recorded by the fiber optic cable 124. The seismic source 126 may include vibro-seismic, dynamite, a shock wave generator and / or an air gun in a pit / basin. In offshore applications, the seismic source 126 may be an air cannon. Fiber optic cable 124 can be part of a distributed acoustic system ("DAS"), which can poll fiber optic cable 124 at an appropriate frequency to obtain seismic data. The seismic data can be recorded by the DAS through the fiber optic cable 124 and can be processed by the information processing system 114 to produce a VSP and / or similar seismic products.
    In examples, a tool 132 can be coupled to the coiled tubing column 102. It should be noted that the tool 132 can be coupled near one end of the coiled tubing column 102 and / or any other suitable location along the coiled tubing column 102. Tool 132 may include a collar locator, a gamma ray device, a source of seismic and / or the like. Π it should be specified that the tool 132 may include a network of geophones arranged at the end of the coiled casing column 102. In examples, the geophones may be arranged at any location along the coiled casing column 102 The geophones can function as calibration points for the position of the fiber optic cable 124 in relation to the coiled tubing column 102. In addition, the geophones can be used to produce angle of attack correction data for the DAS, which can be integrated into the VSP.
    Tool 132 may also include a clamping mechanism. The clamping mechanism can be used for fixing to the borehole 108. The clamping mechanism can be a lateral arm which can extend and can be controlled from the surface. The actuating force to deploy the side arm can come from an electric actuator, a hydraulic system, or depend on a preloaded spring mechanism. The actuation can also come from a fluid pumped inside the coiled tubing column 102, or can be achieved by adding tension or pressure to the coiled tubing column 102. Once in place, the tightening may allow an operator to add tension and / or compression to the coiled tubing column 102 from the surface. During these operations, an operator or a service provider can straighten the coiled tubing column 102 by tension or form a helical contact against the inside diameter of the wall of the compression hole 108. In both cases, stress coupling can exist between the borehole 108 and the coiled tubing column 102, which can produce reliable and accurate VSP data using DAS.
    Without limitation, the tool 132 can include a sonic tool, which can generate tubular waves inside the borehole 108. A fixed sonic tool can generate, in the fluid-filled borehole 108, tubular waves, which can propagate to the surface. These tubular waves can be recorded on the surface by instruments associated with the information processing system 114. The DAS, connected to the fiber optic cable 124, can interrogate the fiber optic cable 124 at an appropriate frequency to obtain seismic data from the tubular waves. Tubular waves can act as an aid for depth calibrations of fiber optic cable 124 or to illuminate elements (not shown) in borehole 108 (i.e., casing junctions, dots ends of casing columns, etc.). Tubular waves can induce a dynamic stress signal in the fiber optic cable 124 which signal can be recorded by the DAS system in the information processing system 114.
    For example, the fiber optic cable 124 can be used as an acoustic receiver to receive the seismic waves 128 emitted from the seismic source 126. The seismic waves 128 can cause vibrations, including variations in stress, in the fiber optic cable 124. An optical interrogator 134 connected to the fiber optic cable 124 detects variations in the light as transmitted through the fiber optic cable 124 due to vibrations, and thus detects the presence (or absence) of seismic waves 128.
    In a DAS system, the optical interrogator 134 can send pulses of light into the fiber optic cable 124 and detect a backscatter of light (for example, coherent Rayleigh backscatter) through the fiber optic cable 124. In an interferometric or Bragg grating system on fiber, the optical interrogator 134 can detect variations in the reflected amplitude and / or the phase of the reflected light (for example, from Bragg grids on fiber, etc. .) through the fiber optic cable 124, in order to detect seismic waves 128. Alternatively, if the fiber optic cable 124 takes the form of a loop which starts from the surface, extends into the well and then returns to the surface, i.e. if both ends of the fiber optic cable 124 are accessible to the surface, changes in amplitude and / or phase of transmitted light can also be used to interrogate the system.
    In examples, tubular waves can be used to provide a depth profile of the position of the cable along the borehole 108. As an example, it can be assumed that a tube wave propagating in a borehole 108 (also called a Stoneley wave) travels at a uniform speed along the segments of the borehole 108. Tracking the position of the wave along the fiber optic cable 124 can therefore be used to recalibrate the position measured in the DAS signal and the position calculated based on the uniform wave speed. Stoneley wave reflections at known locations (such as changes in casing diameter) can also be used to improve depth calibration. In examples, one or more sources of earthquakes can be positioned at the mouth of the well to reduce the amplitude of the surface waves, which can reduce the generation of tubular waves at the surface. Other characteristics of the tubular waves can be interesting for the characterization of the borehole 108 or of a reservoir. For example, fractures in a reservoir can cause amplitude changes and reflections in the tubular waves. Additional resonances can also be observed in the tubular waves following the interaction of the borehole fluid with the fluid present in fractures of the rocks surrounding borehole 108.
    As shown in Figure 2, the coiled tubing column 102 can be used in processing operations. The processing operations may in particular be fracturing operations, cleaning operations, acidification operations and / or operations for rearing with nitrogen, and / or any similar operation. Figure 2 illustrates a fracturing operation. During operations, two sets of coiled tubing columns 102 may be employed. A first column of coiled tubing can be placed in a treatment well 200. A second column of coiled tubing can be placed in an observation well (not shown) to monitor operations inside the treatment well 200. Figure 2 illustrates an example of a treatment well 200 for use with an underground well. In the illustrated embodiment, the treatment well 200 can be used to stimulate a formation 202 (for example, fracturing, acid matrix stimulation, etc.) through the coiled tubing column 102. In examples, the coiled tubing column 102 can be arranged inside conduits (for example a first casing 204, a second casing 206, etc.). The conduits may include a suitable material, such as steel, chromium or alloys. As illustrated, a borehole 208 can extend through formation 202 and / or a plurality of formations 130. While borehole 208 is shown extending generally vertically in formation 202, the The principles described here are also applicable to drill holes that extend at an angle through formation 202, such as horizontal and inclined drill holes. For example, even if Figure 2 shows a vertical well or with a small tilt angle, a high tilt angle or horizontal placement of the well and equipment is also possible. It should also be noted that, while Figure 2 generally illustrates a land operation, those skilled in the art will readily recognize that the principles described here are also applicable to underwater operations which employ platforms and floating or at sea, without departing from the scope of the invention.
    As illustrated in Figure 2, one or more conduits, shown here as a first casing 204 and a second casing 206 may be disposed in the borehole 208. The first casing 204 may take the form of an intermediate casing, a production casing, a lining or another suitable conduit, as will be understood by the skilled person. The second casing 206 can take the form of a surface casing, an intermediate casing or another suitable conduit, as will be understood by a person skilled in the art. Even if not shown, additional conduits can also be installed in hole 208 as desired for a particular application. In the illustrated embodiment, the first casing 204 and the second casing 206 can be cemented to the walls of the drilling hole 208 with cement 210. In a nonlimiting manner, one or more centralizers 212 can be fixed to the first casing 204 and / or to the second casing 206, for example, to center the corresponding conduit in the borehole 208, as well as to protect the additional equipment (for example electromagnetic field detectors, not illustrated).
    In the illustrated embodiment, the treatment well 200 can comprise a hoist 214. In examples, the coiled tubing column 102 can be wound inside the hoist 214. In examples, the hoist 214 can be used to raise and / or lower the coiled tubing column 102 into the borehole 208. The coiled tubing column 102 may also convey fluids, proppants and / or the like downhole to the formation 202. As noted below, additional tools may be provided on the coiled tubing column 102 .
    The processing well 200 may further comprise an information processing system 114. As illustrated, the information processing system 114 can be placed on the surface 215. In examples, the information processing system 114 can be placed at the bottom of the hole. Any suitable technique can be used to transmit signals from the coiled tubing column 102 to the information processing system 114. As illustrated, a communication link 218 (which may be wired or wireless, for example) can be provided. It can transmit data from the fiber optic cable 124 to the information processing system 114. The information processing system 114 may be designed to receive signals from the fiber optic cable 124 which may be representative of measurements made from a tool disposed on the coiled tubing column 102. The processing system 114 information can act as a data acquisition system and possibly as a data processing system that analyzes measurements, for example, to infer one or more training properties 202, measurements and / or information from the tool, and / or which analyzes measurements on the work performed by the treatment well 200.
    FIG. 2 further illustrates the treatment well 200 in operation for introducing a fluid into the fractures 220. The treatment well 200 may comprise a fluid treatment system 222, which may include a supply 224 of fluid, equipment 226 of mixing, and pumping equipment 228 which can be connected to the coiled tubing column 102. The pumping equipment 228 can be fluidly coupled with the fluid supply 224 and the coiled tubing column 102 to transmit fluid 216 fracturing in hole 208. The fluid supply 224 and the pumping equipment 228 may be located above the surface 215 while the borehole 208 is located below the surface 215.
    The treatment well 200 can also be used for injecting a buffer and pre-buffer fluid into the formation 202 at an injection rate greater than the fracture gradient to create at least one fracture 220 in the formation 202 The treatment well 200 can then inject the fracturing fluid 216 into the formation 202 surrounding the borehole 208 through the perforation 230. The perforations 230 can allow communication between the borehole 208 and the formation 202. As illustrated , the perforations 230 can penetrate into the first casing 204 and the cement 210 by allowing communication between the interior of the first casing 204 and the fractures 220. A plug 232, which can be any type of plug for applications of oil field (for example a support plug), can be placed in the borehole 208 below the perforations 230.
    According to the systems, methods and / or compositions of the present invention, the fracturing fluid 216 can be pumped via pumping equipment 228 from the fluid supply 224 by descending inside the first casing 204 through the coiled tubing column 102 and in formation 202 at or above a fracture gradient of formation 202. Pumping of fracturing fluid 216 at or above the fracture gradient of formation 202 can create (or increase) at least one fracture (eg, fractures 220) extending into formation 202 from perforations 230. During fracturing operations, the fiber optic cable 124 can record information and measurements regarding the progress of operations fracturing. This information can be processed and displayed on a VSP at various stages before, during and after a hydraulic fracturing operation. A VSP profile may have been obtained using the coiled tubing column 102 in which the fiber optic cable 124 can be laid before the fracturing operation to be used as a reference base. The recorded information and measurements can be communicated to the information processing system 114 at the surface 215 from the fiber optic cable 124. Using a downhole acoustic source, or one or more sources at surface 215, seismic data can also be collected along with the fracturing operation. The fracturing operation can be divided into stages such that a first type of fluid is pumped, seismic data is obtained, then a second type of fluid is pumped. For example, a first fluid may consist of a buffer fluid, devoid of a propellant, and be used to create fractures 220. While the fracture is held open, seismic data can be obtained. After which the supporting agent can then be pumped, for example into a second fluid, to insert the supporting agent into the fractures created during the fracturing operation. Other seismic data can then be collected both before and after the pressure is released. For example, data can be collected before fluid pumping operations 216 and before the fracture 220 is created. Data can be collected after the pressure is released and the break is closed. Monitoring of fracturing operations can be carried out with the coiled tubing column 102 disposed in the treatment well 200, the coiled tubing column 102 being used for conveying the fracturing fluid, or the coiled tubing column 102 simply monitoring the fracturing work and the fracturing fluid being pumped into the well itself, outside of the coiled tubing 102.
    In examples, by following the position of the fiber optic cable 124 relative to the coiled tubing column 102 (see FIG. 1), and more generally relative to the borehole 108, in situ fiber measurements can be used to map the length of the fiber optic cable 124. This may include a strain measurement, a fiber curvature measurement, a fiber temperature measurement and / or a measurement of the backscattered light energy. A stress measurement can be carried out by means of a Brillouin scattering operation (via a Brillouin optical temporal reflectometry, BOTDR, or a Brillouin optical temporal analysis, BOTDA), or a Rayleigh scattering using optical reflectometry in the frequency domain (OFDR). Fiber curvature measurement can be performed using time polarization optical reflectometry (P-OTDR) or frequency domain polarization optical reflectometry (P-OFDR). A fiber temperature measurement can be performed using a Raman effect DTS. A SAR measurement of the backscattered light energy can be performed using an automatic thresholding program, T fiber end is defined on the DAS channel for which the non-resonant lines of backscattered light energy. The purpose of these measurements may be to calculate the length of the fiber optic cable 124, and its distributed curvature. The distributed curvature provides a measure of the curvature of the fiber optic cable 124 and can therefore determine the slope of the spiral or sinusoidal pattern formed by the cable inside the coiled tubing column 102 and the slope of the spiral pattern or sinusoidal produced by the wrapped casing column 102 inside the borehole 208. These measurements can help identify a position along the fiber optic cable 124, where the measurements were recorded by the DAS system during the acquisition of VSP data. In examples, these measurements can be used in conjunction with acoustic methods using the Stoneley (tubular) waves described above.
    The SAR measurements provide a single stress component, in the axial direction of the fiber optic cable 124, and, depending on the type of waves generated in the borehole 208, it may be advantageous to be able to measure other components of the constraint. This is possible with a coiled tubing column 102 in which geophones or accelerometers can be attached. Geophones and accelerometers may be able to detect, measure and / or record a movement through the coiled tubing column 102. In examples, geophones and accelerometers include optical or electrical sensors. The output of electrical geophones can be converted to an acoustic signal using piezoelectric or magnetostrictive elements which can produce a strain signal inside fiber optic cable 124 in accordance with the measured signal from a geophone. This conversion from the geophone or accelerometer output can be done in an analog signal domain (for example, a tone frequency can be produced, which can vary with signal strength) or the electrical signals from the transducers can first of all be digitized by local electronics and routed digitally (or by processed analog signals) to the optical fiber using an electro-acoustic transducer placed near the fiber optic cable 124. Other sensors, such as an EM, hydrophone, or temperature probes can also be placed along the coiled tubing column 102 and their signal converted to produce an acoustic response.
    The conversion may include producing a frequency tone, the value of which may be associated with the quantity measured. The same frequency signal can also be used as a known location point to further assist in calibrating the position of the fiber optic cable 124 along the coiled tubing column 102 and, more generally, within the hole 208 drilling. The output of geophones, accelerometers or hydrophones can be used to help interpret VSP signals. For example, they can be used to better distinguish P and S waves in the data collected by the DAS. The sensors deployed along the coiled tubing column 102 and using the fiber optic cable 124 as the telemetry channel (acoustic telemetry) can be contained within the coiled tubing column 102 or attached externally to the tubing column coiled 102. The sensors may also be present in the borehole 208 (for example, behind the casing) and use the fiber optic cable 124 as an acoustic telemetry channel while the coiled tubing column 102 may be disposed in the hole 208 drilling.
    In examples, it may be desirable to deploy a coiled tubing column 102 into a borehole 208 for an extended period of time, to be used for measurements during the extended period of time. In addition, a "detection column" can also be deployed in an observation well, and can even be cemented in place to remain permanently in hole 208.
    The foregoing description provides various examples of the systems and methods of use described herein which may contain different process steps and combinations of alternative components.
    Item 1. A system may include a coiled tubing column and an optical fiber cable disposed in the coiled tubing column, the optical fiber cable being forcibly coupled to the coiled tubing column.
    Item 2. System according to item 1, in which the stress coupling between the coiled tubing column and the optical fiber cable is formed by means of a weld, a hook, a magnetization or a expansion tube.
    Item 3. System according to items 1 or 2, in which the fiber optic cable is soldered to an inside diameter of the coiled tubing column.
    Item 4. System according to items 1 to 3, in which the optical fiber cable is longer than the coiled tubing column in which the optical fiber cable is arranged so that the additional length of the optical fiber cable is arranged in the wrapped tubing column.
    Statement 5. The system of claims 1 to 4, further comprising a source of earthquake, in which the source of earthquake is designed to reduce an amplitude of a surface wave at a well mouth.
    Statement 6. System according to statements 1 to 5, further comprising a tool, in which the tool is coupled to the coiled tubing column and the tool is at least a geophone, a collar locator, a gamma ray device or a source of vibroseismic.
    Item 7. The system of items 1 to 6, further comprising a clamping mechanism coupled to the coiled tubing column and wherein the clamping mechanism secures the coiled tubing column to a wall of a borehole.
    Statement 8. The system of statements 1 to 7, further comprising a sonic tool coupled to the coiled tubing column and in which the sonic tool generates a tubular wave.
    Statement 9. System according to statements 1 to 8, further comprising a distributed acoustic detection system. The distributed acoustic detection system may include an optical interrogator, in which the optical interrogator is connected to the fiber optic cable. The optical interrogator can be designed to transmit light through the optical fiber cable and detect a change in light as the light passes through the optical fiber cable. The distributed acoustic system may further include an information processing system, in which the information processing system may be able to process the variation in light to determine a property of the borehole.
    Statement 10. System according to statements 1 to 9, in which the coiled tubing column is stress-coupled to a borehole and the stress-coupling is formed by means of a weld, a hook, a magnetization or an expansion tube.
    Statement 11. System according to statements 1 to 10, in which the optical fiber cable is arranged in a bundle with the electric cable, one or more electric wires being in the electric cable.
    Statement 12. The system of claims 1 to 11, wherein the optical fiber cable is a plurality of optical fibers.
    Statement 13. A method of performing a wellbore operation may include arranging a tubing column wound in a wellbore, an optical fiber cable being forcibly coupled to the coiled tubing column, and the measurement of at least one property of the borehole with the fiber optic cable.
    Statement 14. Method according to statement 13, further comprising processing the at least one property of the borehole with an information processing system, creating a vertical seismic profile from the minus a property of the borehole; and displaying a vertical seismic profile for an operator.
    Statement 15. Method according to statements 13 or 14, in which the fiber optic cable is soldered to an inside diameter of the coiled tubing column.
    Statement 16. Method according to statements 13 to 15, in which the optical fiber cable is longer than the coiled tubing column in which the optical fiber cable is arranged so that the additional length of the optical fiber cable is arranged in the wrapped tubing column.
    Statement 17. A method according to statements 13 to 16, further comprising a source of earthquakes, wherein the source of earthquakes is designed to reduce an amplitude of a surface wave at a mouth of a well.
    Statement 18. A method according to statements 13 to 17, further comprising arranging a second column of tubing wound in a second borehole and coupling the at least one sensor to the second column of wrapped tubing.
    Statement 19. A method according to statements 13 to 18, in which the optical fiber cable is arranged in a bundle with an electric cable, one or more electric wires being in the electric cable.
    Statement 20. Method according to statements 13 to 19, the optical fiber cable being a plurality of optical fibers.
    It should be understood that, although specific examples may be given here, the present invention covers all combinations of the examples described, including, but not limited to, the various combinations of components, the combinations of process steps and the system properties. It should be understood that the compositions and methods are described with the terms "comprising", "containing" or "including" various components or steps, and the compositions and methods may also "consist essentially" or "consist" of the various components and various stages.
    For the sake of brevity, only certain ranges are explicitly described here. However, ranges from any lower limit can be combined with any upper limit to indicate a range that is not explicitly stated; similarly, ranges from any lower limit can be combined with any other lower limit to indicate a range that is not explicitly stated. Likewise, ranges from any upper limit can be combined with any other upper limit to indicate a range that is not explicitly stated. In addition, whenever a numeric range with a lower limit and an upper limit is described, any number and any included range falling within the range are described specifically. In particular, each range of values (of the form, "from about a to about b" or, equivalently, "from about a to b" or, equivalently, "from about ab") described here must be understood to include each number and range included in the wider range of values even if this is not explicitly stated. Thus, each specific point or value can be used as its lower or upper limit combined with any other specific point or value or any other lower or upper limit, to indicate a range which is not explicitly indicated.
    Consequently, the present examples are perfectly suited to achieve the purposes and take advantage of the advantages mentioned and those inherent in the present invention. The particular examples described above are given for illustration purposes only, and may be modified and practiced in different but equivalent ways which will be apparent to those skilled in the art benefiting from the teachings given herein. Even if specific examples are cited, the invention covers all combinations of all examples. In addition, there are no limitations to the details of construction or design shown here, except the limitations described in the claims below. Likewise, the terms in the claims have their usual and natural meaning unless clearly and explicitly defined to the contrary by the patent owner. It is therefore obvious that the particular examples described for purposes of illustration above can be replaced or modified and that all these changes are considered to be within the scope and the spirit of these examples. In the event of a conflict concerning the use of a word or term in this description and one or more patents or other documents which may be incorporated here by reference, the definitions which conform to this description must be adopted.
    权利要求:
    Claims (15)
    [1" id="c-fr-0001]
    1. System (100) for obtaining vertical seismic profiles in boreholes (108), comprising:
    a coiled tubing column (102); and an optical fiber cable (124) disposed in the coiled tubing column, and wherein the optical fiber cable (124) is forcibly coupled to the coiled tubing column.
    [2" id="c-fr-0002]
    2. System (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, in which the stress coupling between the rolled up casing column (102) and the optical fiber cable (124) is formed by means of a weld, a hook, a magnetization or an expansion tube.
    [3" id="c-fr-0003]
    3. System (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, in which the optical fiber cable (124) is welded to an inside diameter of the rolled up casing column (102 ), and optionally in which the optical fiber cable (124) is longer than the coiled tubing column in which the optical fiber cable is arranged so that the additional length of the optical fiber cable is disposed in the casing column coiled (102).
    [4" id="c-fr-0004]
    4. The system (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, further comprising a source of earthquakes (126), in which the source of earthquakes is designed to reduce an amplitude d '' a surface wave at a well mouth.
    [5" id="c-fr-0005]
    5. System (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, further comprising a tool, in which the tool is coupled to the rolled up casing column (102) and l the tool is at least a geophone, a collar locator, a gamma ray device or a source of earthquake seismic and possibly a clamping mechanism coupled to the coiled tubing column (102) and in which the clamping mechanism fixes the column of casing wound to a wall of a borehole (108).
    [6" id="c-fr-0006]
    6. System (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, further comprising a sonic tool coupled to the coiled tubing column (102) and in which the sonic tool generates a tubular wave.
    [7" id="c-fr-0007]
    7. System (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, further comprising a distributed acoustic detection system, in which the distributed acoustic detection system comprises:
    an optical interrogator (134), in which the optical interrogator is connected to the optical fiber cable (124) and the optical interrogator (134) is designed to:
    transmitting light through the fiber optic cable; and detecting a change in light as the light passes through the optical fiber cable (124); and an information processing system (114), in which the information processing system is capable of processing the variation of light to determine a property of the borehole (108).
    [8" id="c-fr-0008]
    8. A system (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, in which the coiled tubing column (102) is constrained to a borehole (108) and the stress coupling is formed by means of a weld, a hook, a magnetization or an expansion tube.
    [9" id="c-fr-0009]
    9. System (100) for obtaining vertical seismic profiles in boreholes (108) according to claim 1, in which the optical fiber cable (124) is arranged in a bundle with an electric cable, in which the cable electrical is one or more electrical wires, and optionally wherein the optical fiber cable (124) is a plurality of optical fibers.
    [10" id="c-fr-0010]
    10. A method of performing a wellbore operation (108) comprising: providing a coiled tubing column (102) in a wellbore (108) and in which a fiber optic cable (124) is constrained to the coiled tubing column; and measuring at least one property of the borehole (108) with the fiber optic cable.
    [11" id="c-fr-0011]
    11. The method of claim 10, further comprising processing the at least one property of the borehole (108) with an information processing system (114), creating a vertical seismic profile from at least one property of the borehole (108); and displaying a vertical seismic profile for an operator.
    [12" id="c-fr-0012]
    12. The method of claim 10, wherein the optical fiber cable (124) is welded to an inside diameter of the coiled tubing column (102), and optionally wherein the optical fiber cable (124) is longer than the coiled tubing column in which the optical fiber cable (124) is arranged such that the additional length of the optical fiber cable is disposed in the coiled tubing column.
    [13" id="c-fr-0013]
    13. The method of claim 10, further comprising a source of earthquakes (126), wherein the source of earthquakes is adapted to reduce an amplitude of a surface wave at a mouth of a well.
    [14" id="c-fr-0014]
    14. The method of claim 10, further comprising providing a second column of tubing wound in a second borehole and coupling at least one sensor on the second column of tubing wound.
    [15" id="c-fr-0015]
    15. The method of claim 10, wherein the optical fiber cable (124) is arranged in a bundle with an electric cable, in which the electric cable is one or more electric wires, and optionally in which the optical fiber cable ( 124) is a plurality of optical fibers.
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    同族专利:
    公开号 | 公开日
    WO2019094140A1|2019-05-16|
    US20210131276A1|2021-05-06|
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    法律状态:
    2019-10-30| PLFP| Fee payment|Year of fee payment: 2 |
    2020-05-15| PLSC| Search report ready|Effective date: 20200515 |
    2021-05-14| RX| Complete rejection|Effective date: 20210407 |
    优先权:
    申请号 | 申请日 | 专利标题
    US201762584554P| true| 2017-11-10|2017-11-10|
    US62584554|2017-11-10|
    PCT/US2018/055215|WO2019094140A1|2017-11-10|2018-10-10|System and method to obtain vertical seismic profiles in boreholes using distributed acoustic sensing on optical fiber deployed using coiled tubing|
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