TECHNICAL FIELD
This disclosure relates to wellbore drilling and completion.
BACKGROUND
In hydrocarbon production, a wellbore is drilled into a hydrocarbon-rich geological formation. After the wellbore is partially or completely drilled, a completion system is installed to secure the wellbore in preparation for production or injection. The completion system can include a series of casings or liners cemented in the wellbore to help control the well and maintain well integrity.
Flexible cables such as fiber optic cables or electric cables are used for various downhole sensing, power, and/or data transmission purposes.
SUMMARY
This disclosure describes a system and method for deploying a flexible cable in a downhole conduit.
Certain aspects of the subject matter herein can be implemented as a method of deploying a flexible cable in a wellbore. The method includes carrying, by a tubular assembly, a cable spool cartridge into the wellbore. The cable spool cartridge is attached to an exterior of the tubular assembly and contains the flexible cable. A first end of the flexible cable is attached to a buoyancy device, and the buoyancy device is releasably attached to the cable spool cartridge. A fluid is flowed by the tubular assembly in a downhole direction through an interior of the tubular assembly and in an uphole direction within an annulus at least partially defined by the exterior of the tubular assembly. The fluid has a greater density than the buoyancy device. The buoyancy device is released by the cable spool cartridge, and the buoyancy device is configured to travel after release in the uphole direction with the fluid and thereby pull the flexible cable from the cable spool cartridge and into the annulus.
An aspect combinable with any of the other aspects can include the following features. The flexible cable comprises a fiber optic cable. A light signal is transmitted through the fiber optic cable.
An aspect combinable with any of the other aspects can include the following features. The fluid comprises a cement slurry. A position of the cement slurry in the annulus is detected based on a signal from the flexible cable.
An aspect combinable with any of the other aspects can include the following features. A change in a mechanical property of cement in the annulus is detected based on a signal from the flexible cable.
An aspect combinable with any of the other aspects can include the following features. The mechanical property is a strain load.
An aspect combinable with any of the other aspects can include the following features. The flexible cable comprises an electric cable. A change in an electrical resistance of cement in the annulus is detected.
An aspect combinable with any of the other aspects can include the following features. The cable spool cartridge includes a plurality of flexible cables. Each of the flexible cables has a respective first end attached to the buoyancy device.
An aspect combinable with any of the other aspects can include the following features. A first casing has been installed in the wellbore. The tubular assembly includes a second casing. The annulus is defined by the interior of the first casing and the exterior of the second casing.
An aspect combinable with any of the other aspects can include the following features. A second cable spool cartridge is attached to an exterior of a third casing. The second cable spool cartridge contains a second flexible cable, and a first end of the second flexible cable is attached to a second buoyancy device releasably attached to the second cable spool cartridge. The third casing assembly is lowered into the wellbore within the second casing, and the second cable spool cartridge is positioned proximate to the downhole end of the third casing within a second annulus defined by the interior of the second casing and the exterior of the third casing. A fluid is flowed in an uphole direction in the second annulus, the fluid having a greater density than the second buoyancy device. The second buoyancy device is released from the second cable spool cartridge, thereby allowing the first end of the second flexible cable to travel in an uphole direction with the fluid and thereby pull the second flexible cable from the second cable spool cartridge and into the second annulus.
An aspect combinable with any of the other aspects can include the following features. The first end of the flexible cable and the first end of the second flexible cable are attached to a data acquisition unit.
An aspect combinable with any of the other aspects can include the following features. The flexible cable comprises a power cable.
Certain aspects of the subject matter herein can be implemented as a downhole deployment system for a flexible cable. The system includes a cable spool cartridge configured to be attached to an exterior of a wellbore assembly at a downhole location. The cable spool cartridge contains the flexible cable. A buoyancy device is releasably attached to a first end of the flexible cable and releasably attached to the cable spool cartridge. The buoyancy device is configured to be released from the cable spool cartridge to travel in an upwards direction within a conduit at least partially filled with a fluid having a higher density than the buoyancy device, thereby pulling the flexible cable from the cable spool cartridge and into the conduit.
An aspect combinable with any of the other aspects can include the following features. The flexible cable comprises a fiber optic cable.
An aspect combinable with any of the other aspects can include the following features. The flexible cable comprises an electric cable.
An aspect combinable with any of the other aspects can include the following features. The fluid comprises a cement slurry.
An aspect combinable with any of the other aspects can include the following features. The wellbore assembly comprises a second casing within a first casing, and the conduit comprises an annulus defined by the interior of the first casing and the exterior of the second casing.
An aspect combinable with any of the other aspects can include the following features. The system includes a shear pin configured to release the buoyancy device in response to plug landing in a plug seat.
An aspect combinable with any of the other aspects can include the following features. The system includes an electronic control unit configured to release the buoyancy device in response to a signal from a circuit closing in response to pumpable plug landing in a downhole plug seat, a signal generated by a sensor configured to sense an arrival of a pumpable plug at a downhole location, or a signal from an operator.
An aspect combinable with any of the other aspects can include the following features. A data acquisition unit attachable to an end of the flexible cable.
An aspect combinable with any of the other aspects can include the following features. The data acquisition unit is a laser box.
An aspect combinable with any of the other aspects can include the following features. The cable spool cartridge includes a plurality of flexible cables, each of the plurality of flexible cables having a respective first end, and wherein each respective first end of the plurality of flexible cables is attached to the buoyancy device.
An aspect combinable with any of the other aspects can include the following features. The flexible cable comprises a power cable.
The details of one or more implementations of the subject matter of this disclosure are set forth in the accompanying drawings and the description. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.
BRIEF DESCRIPTION OF DRAWINGS
FIG. 1 is a drawing of an example cable deployment system in accordance with an embodiment of the present disclosure.
FIG. 2 is a process flow diagram of a method for deployment of a cable accordance with an embodiment of the present disclosure.
FIGS. 3A-3D are drawings of a deployment of a cable in a wellbore conduit in in accordance with an embodiment of the present disclosure.
FIG. 4 is a drawing of a well system wherein cables are deployed in multiple casing-casing annuli in accordance with an embodiment of the present disclosure.
FIG. 5 is a drawing of an example triplet cable deployment system in accordance with an embodiment of the present disclosure.
FIG. 6 is a drawing of a well system wherein multiple triplet cables are deployed in multiple casing-casing annuli in accordance with an embodiment of the present disclosure.
FIG. 7 is a drawing of a well system wherein each cable of a triplet cable set is connected to a separate data acquisition unit in accordance with an embodiment of the present disclosure.
FIGS. 8A-8B are drawings of a fiber optic acoustic sensor system in accordance with an embodiment of the present disclosure.
DETAILED DESCRIPTION
This disclosure describes a system, tool, and method for deploying a downhole flexible cable.
Downhole flexible cables such as fiber optic cables or electric cables are used for various downhole sensing and/or data transmission purposes. For example, it may be advantageous to deploy a fiber optic cable within the cement sheath along the vertical length of the cemented annular space in between two casing strings, called the casing-casing annulus. Such a fiber optic cable can be deployed in the casing-casing annulus during cementing operations to, for example, measure the height of the cement slurry as it exits the casing shoe and advances towards the surface within the annulus.
Alternatively or in addition, a fiber optic cable installed in the casing-casing annulus after cement placement can be used to detect the change in mechanical properties of the cement as the cement dehydrates and hardens.
Alternatively or in addition, a fiber optic cable installed in the casing-casing annulus can be used to measure strain or other properties throughout the life of the well, thus detecting pressure-induced events and/or any cracks or other failures in the cement sheath.
The system, tool, and method of the present disclosure can efficiently deploy a fiber optic cable or other cable in a casing-casing annulus or other conduit with a low risk of cable breakage or other damage, thus resulting in more efficient and effective detection and monitoring of the cement sheath or other downhole conditions with a low risk of failure. Furthermore, in some embodiments, the system, tool, and method of the present disclosure can efficiently deploy multiple cables in parallel in an annulus or other conduit, thus enabling redundancy and/or multiple sensing modes in the same conduit.
FIG. 1 illustrates a cable deployment system 100 in accordance with an embodiment of the present disclosure. In the illustrated embodiment, cable deployment system 100 includes a tubular assembly 101 which includes casing shoe track 102 and casing string 104. Casing shoe track 102 is attached to the downhole end of casing string 104. In some embodiments, tubular assembly 101 can include more, fewer, or different components.
Cable spool cartridge 120 is attached to an exterior surface of casing shoe track 102. Cable spool cartridge 120 includes a cable 122 spooled inside of a housing and buoyancy device 124 attached to a first end of cable 122. In some embodiments, cable 122 can be a fiber optic cable or other sensor cable. In some embodiments, cable 122 can be an electric cable or other power cable. The second end of cable 122 is attached to cable spool cartridge 120 and the remaining length of cable 122 is spooled within cable spool cartridge 120.
In the embodiment shown in FIG. 1, casing shoe track 102 includes a float collar 130, plug seat 132, and float shoe 134. In the illustrated embodiment, and as described in more detail with respect to FIGS. 2 and FIGS. 3A-3D, system 100 is configured such that landing a plug in plug seat 132 will break shear pin 136, which thereby releases buoyancy device 124 from cartridge 120.
FIG. 2 is a process flow diagram of a method 200 for deployment of a flexible cable in accordance with an embodiment of the present disclosure. The method is described with reference to the components described in reference to FIGS. 1 and 3A-3D.
At step 202, a wellbore assembly carries a cable spool cartridge (such as cable spool cartridge 120 from FIG. 1) into a wellbore such as wellbore 300 as shown in FIG. 3A. In the embodiment shown in FIGS. 3A-3D, the wellbore assembly is a tubular assembly, specifically, tubular assembly 101 including casing string 104 and casing shoe track 102 as described in reference to FIG. 1, and cable spool cartridge 120 is attached to the exterior of casing shoe track 102. In some embodiments, the cable spool cartridge may be attached to another suitable wellbore assembly such as a downhole tool (such as a packer) or a production tubing or work string. In some embodiments, the wellbore assembly to which the cable spool cartridge is attached is a non-tubular assembly.
In the embodiment of the present disclosure shown in FIG. 3A, cable spool cartridge 122 may contain a cable 122 (as illustrated in FIG. 1) that is a fiber optic cable; in some embodiments of the present disclosure, cable spool cartridge may contain an electrical cable or other suitable flexible cable spooled in the cartridge instead of or in addition to a fiber optic cable.
With casing string 104 lowered into the wellbore 300, a casing-casing annulus 304 is formed by the exterior surface of casing string 104 and the interior surface of outer casing 302. In FIG. 3A, casing string 104 has not yet been cemented in place, and drilling fluid 306 or another suitable displacement fluid fills casing-casing annulus 304.
At step 204 (FIG. 2), a fluid is flowed in the conduit containing the cable spool cartridge. In the embodiment shown in FIGS. 3A-3D, the fluid is a cement slurry 310 and the conduit is the casing-casing annulus 304. In some embodiments, the fluid can be drilling fluid or a displacement fluid flowed through the annulus prior to cementing.
As shown in FIG. 3B, cement slurry 310 is first flowed in a downhole direction behind a plug 308 within the interior of tubular casing string 104 and through casing shoe track 102. As shown in FIG. 3C, plug 308 lands on the landing seat of casing shoe track 102. Plug 308 has a rupture disc 312 configured to rupture when a pressure at which cement slurry 310 exceeds a pre-determined amount. At FIG. 3D, as pressure continues to increase, rupture disc 312 ruptures, allowing cement slurry 310 to exit the downhole end of casing string 104 and fill casing-casing annulus 304.
At 206, the buoyancy device 124 is released and cable 122 is pulled into the conduit. In the embodiment shown in FIGS. 1 and 3A-3D, the release is triggered by the landing of plug 308 into landing seat 132. Specifically, in the illustrated embodiment, shear pins 136 connect landing seat 132 with buoyancy device 124. Shear pins 136 are configured to break at a lower pressure than that required to break rupture disc 312. As shown in FIG. 3C, plug 308 has landed on the landing seat of casing shoe track 102. The pressure at which cement slurry 310 is pumped is increased until shear pins 136 break. Breakage of shear pins 136 releases buoyancy device 124 from cartridge 120.
In some embodiments, buoyancy device 124 can be released from cable spool cartridge 120 by other or additional means. In some embodiments, cable spool cartridge 120 is configured to release buoyancy device 124 in response to casing shoe track 102 being pushed against the bottom of the well at a predetermined slack-off weight. In some embodiments, cable spool cartridge 120 is configured to release buoyancy device 124 in response to rotation of casing string 104 by a pre-determined number of rotations.
In some embodiments, an electronic control unit (ECU) can be attached to cable spool cartridge 120 and the ECU can be configured to release buoyancy device 124 in response to a detection of plug 308 arriving in casing shoe track 102 and/or landing in landing seat 132. The ECU can be connected to sensor(s) and can include a processor, a power source (such as a battery), and a release mechanism. Detection of plug 308 to trigger release by the ECU can be by one of several methods: In some embodiments, the seat of the plug has two un-connected metal sides, and the plug has a metal component such that landing of the plug closes an electrical circuit which provides a signal to the ECU, in response to which buoyancy device 124 is released. In some embodiments, landing seat 132 is equipped with a strain gauge that senses the pressure applied by plug 308 after landing, and the ECU is configured to release buoyancy device 124 when the strain reaches a predetermined amount. In some embodiments, the ECU is equipped with a sensor that detects plug 308 and is configured to release buoyancy device 124 when plug 308 arrives in proximity of the sensor, such as a magnetic sensor, sonar sensor, radio-frequency identification (RFID), or other suitable sensor. In some embodiments, the ECU is configured to receive a signal from the surface (such as a pressure signal) and thereby release buoyancy device 124 in response to receipt of the signal.
Buoyancy device 124 is configured to have a lower density than the cement in cement slurry 210. In the illustrated embodiment, as shown in FIG. 3D, as cement slurry 310 travels in an uphole direction past cartridge 120, buoyancy device 124 (which has been released from cartridge 120 as described above) tends to float in an upward direction along with the flow of cement slurry 310. As buoyancy device 124 floats in the uphole direction, the first end of cable 122 (attached to buoyancy device 124) is pulled out of cartridge 120 and into annulus 304. A second end of cable 122 remains attached to cartridge 120. In this way, as cement slurry 210 and buoyancy device 124 continue in an uphole direction and approach the surface, a length of cable 122 is deployed in the casing-casing annulus 304 for the full vertical distance (or a substantial portion of the vertical distance) from the cartridge 120 at the downhole end of casing string 104 up to a surface location (or proximate a surface location)
At step 208 (FIG. 2), upon reaching the surface or other final desired vertical location of the first (uphole) end of cable 122, the first end can be disconnected from buoyancy device 124 and attached to a surface unit such as a data acquisition unit, control unit, power unit, measurement unit, or other component which is disposed at the surface at the wellhead or at another suitable location. In some embodiments, cable 122 is a sensor cable such as a fiber optic cable and is attached to a data acquisition unit configured to transmit and/or receive a signal to or from the fiber optic cable, such that data can be collected and processed on the surface. In embodiments wherein the cable 122 is a fiber optic cable, the data acquisition unit can be a laser box configured to transmit and/or receive a light signal to or from fiber optic cable 122. The data acquisition unit can in some embodiments include a signal processing circuit and a reference fiber optic cable which receives a signal from a reference signal generator.
In some embodiments, cable 122 is a power cable and attached to a surface power source after disconnection from buoyancy device 124. In such embodiments where cable 122 is a power cable, cartridge 120 can include a connection to a downhole component such that power from the surface power source can be transmitted from the power source via cable 122 to the downhole component.
The system and method illustrated in FIGS. 1-3 can be used to deploy a fiber optic cable or other cable in a downhole conduit such as a casing-casing annulus. In one embodiment of the present disclosure, a fiber optic cable can be deployed in the casing-casing annulus before cementing with drilling fluid or other suitable fluid, such that subsequent cementing operations can be monitored. In such an embodiment, the deployed fiber optic cable can be used to, for example, measure the height of the cement slurry as it exits the casing shoe and advances towards the surface within the annulus. The higher density cement slurry can be detected as the untethered fiber optic cable will exhibit increased strain load along the portions of the annulus in which the cement is pumped. Through similar logic the position of lower density spacers pumped ahead of the cement as well as the displaced mud can also be derived.
In some embodiments, a fiber optic cable can be installed before or along with the cement slurry and can be used to detect the change in mechanical properties of the cement as the cement dehydrates and hardens. As the cement slurry gains compressive strength, this will be detected as the untethered fiber cable will exhibit increased strain load along the portions of the annulus in which the cement is hardening. This will allow the comparison of the planned cement properties to be compared to what is actually achieved during field application. The cement may not reach the designed properties due to several reasons, such as, for example, unexpected operational conditions that may lead to cement contamination, undiagnosed wellbore geometry considerations such as over-gauge hole, or lost circulation events during the cementing operation. Whatever the cause, detection of the failure of the cement to reach its desired mechanical properties (considered as a function of stress over time) can aid in diagnoses and the need for remediation can be considered. Wellbore integrity can therefore be improved as the well will only become increasingly hard to perform any remediation of the cement sheath once additional strings of casing and cement are added as the well is deepened. In some embodiments, installation of a temperature sensor will allow these properties to be examined with respect to the temperature gradient as calculated along the casing string from the casing shoe to surface.
Alternatively or in addition, a fiber optic cable installed in the casing-casing annulus using the system and method illustrated in FIGS. 1-3 can be used to measure strain or other properties throughout the life of the well, thus detecting pressure-induced events and/or any cracks or other failures in the cement sheath. Typically, cement slurries are designed to reach designed mechanical properties over the course of a few days, but the value of measuring the strain measured along the cemented fiber cable allows well integrity to be monitored for years, throughout the life of the well for detection of any degradation of the cement that may occur. By monitoring the stress along the cemented annuli, the pressure induced events that result in a change of the radial stress across the cement sheath can be monitored and any failure in the cement sheath can be detected. This can be beneficial for assessing any need for repair and continued operation of the wellbore throughout its producing life.
In some embodiments, the flexible cable deployed using the method and system described herein can be a cable other than a fiber optic cable, such as an electric cable, instead of or in addition to a fiber optic cable. For example, cracks or flaws in the cement sheath can be detected by configuring the cement to have piezoelectric properties or by adding carbon fibers to the cement, such that such cracks or flaws can be detected by an electric cable as a change in the electrical resistance of the cement.
In some circumstances, a well may be drilled with multiple casing strings, such that a well may have multiple casing-casing annuli. In some embodiments of the present disclosure, cables can be deployed in each annulus of such a multi-casing system, to allow for monitoring and/or data transmission within each annulus, using the method and system illustrated in FIGS. 1-3 for each casing string in sequence. As shown in FIG. 4, multiple cable spool cartridges 120 may be used, with a cable spool cartridge 120 attached to the exterior of the downhole ends of each casing string as that casing string is lowered into the wellbore 400, and, using the method as described above with respect to FIGS. 1-3 with respect to each cartridge, a cable may be deployed within each annuli. As shown in FIG. 4, a first cable 420 is deployed in the annulus between the wellbore 400 and the first (outer) casing 402. A second cable 422 is deployed within the annulus between the first (outer) casing 402 and the second casing 404. A third cable 424 is deployed within the annulus between the second casing 404 and the third casing 406. A fourth cable 426 is deployed in the annulus between the third casing 406 and the fourth (inner) casing 408 (or production tubing).
In the illustrated embodiment, each of cables 420, 422, 424, and 426 are attached to a common data acquisition unit 450. In some embodiments, each of the cables from the different annuli may be attached to a different data acquisition unit. Data acquisition unit 450 can be disposed at the surface or at another suitable location.
FIG. 5 illustrates an example triplet cable deployment system in accordance with an embodiment of the present disclosure. In the embodiment shown in FIG. 5, cable spool cartridge 502 is configured to house three spools, each of which contains a flexible cable. A first spool contains a first cable 504, a second spool contains a second cable 506, and a third spool contains a third cable 508. Cables 504, 506, and 508 can in some embodiments comprise a fiber optic cable. One end of each of cables 504, 506, and 508 is attached to a buoyancy device 520, and the other end of each of cable 504, 506, and 508 is attached to the cable spool cartridge 502. Buoyancy device 520 is releasable attached to cable spool cartridge 502 in a manner as described in reference to one of the various embodiments as described in reference to FIGS. 3A-3D above. In other embodiments, a different cable spool cartridge 502 may be configured to house a different number of spools, such as four or five.
The embodiment shown in reference to FIG. 5 provides a system for deploying multiple (in the illustrated embodiment, three) cables within vertical length of a casing-casing annulus or other downhole conduit. Although three cables are illustrated in FIG. 5, in some embodiments another number (such as four or five) can be deployed by increasing the number of spools within cartridge 502. In some embodiments, the preferable number of cable may depend on the volume of the casing-casing annulus or other conduit into which the cables are to be deployed. Multiple cables equally spaced apart can ensure the whole cement sheath area, the space between the outer diameter of the casing and the wellbore wall, is covered for real-time distributed sensing. Multiple cables can provide redundancy and increase the probability of at least one cable reaching the surface. Another advantage of having multiple cables is the ability to interrogate multiple parameters. Small events in the cable are related to multiple parameters (such as temperature, pressure and acoustic energies) and it can be challenging to discriminate multiple parameters from one cable. While it is possible to provide simultaneous measurements of multiple parameters, there is an inherent trade-off between performance parameters such as sensing range, spatial resolution, and sensing resolution. Therefore, having dedicated cables for specific parameters can increase the accuracy of casing-casing annulus evaluation parameters.
FIG. 6 is a drawing of a well system wherein multiple triplet cables are deployed in multiple casing-casing annuli in accordance with an embodiment of the present disclosure. As shown in FIG. 6, multiple triplet cable spool cartridges 502 may be used, with a triplet cable spool cartridge 502 attached to the exterior of the downhole ends of each casing string as that casing string is lowered into a wellbore 600, and, using the method as described above with respect to FIGS. 3A-3D and FIG. 5 with respect to each cartridge, a cable triplet may be deployed within each annuli as described in reference to FIG. 5. As shown in FIG. 6, a first cable triplet 620 is deployed in the annulus between wellbore 600 and the first (outer) casing 602. A second cable triplet 622 is deployed within the annulus between the first (outer) casing 602 and the second casing 604. A third cable triplet 624 is deployed within the annulus between the second casing 604 and the third casing 606. A fourth cable triplet 626 is deployed in the annulus between the third casing 606 and the fourth (inner) casing 608 (or production tubing).
In the illustrated embodiment, each of cable triplets 620, 622, 624, and 626 are attached to a common data acquisition unit 650. In some embodiments, each of the cables from the different annuli may be attached to a different data acquisition unit.
FIG. 7 is a drawing of a well system wherein each cable of a triplet cable set is connected to a separate data acquisition unit in accordance with an embodiment of the present disclosure. The cables 710, 712, and 714 are components of a triplet of cables deployed in a casing-casing annulus 702 as described in reference to FIG. 5. Cable 710 is connected to first data acquisition unit 750. Cable 712 is connected to a second data acquisition unit 752. Cable 714 is connected to third data acquisition unit 754. Each cable and data acquisition unit can be configured to a single type or mode of sensor, or may each reflect a different type or mode of sensor. For example, in the illustrated embodiment, cable 710 attached to first data acquisition unit 750 can be a fiber optic cable connected to a single-point sensor 720. Cable 712 attached to second data acquisition unit 752 can be a fiber optic cable connected to multiple point sensors 730. Cable 714 attached to third data acquisition unit 754 can comprise a fiber optic cable as part of a distributed temperature sensing system. Data acquisition units 750, 752, and 754 can be disposed at the surface or at another suitable location.
As shown in FIG. 7, by easily and cost-effectively deploying multiple cables within the casing-casing annulus, the system can be readily configured for different sensing modes within a single annulus. Single point fiber optic sensing is an intrinsic or extrinsic measurement of a single sensor on an optical fiber. Single point strain sensing can be achieved by many mechanisms knowingly by an individual fiber Bragg grating (FBG), long period gratings (LPG) or Fabry-Perot and Mach-Zehnder systems. Single-point fiber sensors, even when multiplexed to form multi-point fiber sensors, may not intrinsically provide the wealth of information that can be provided through distributed optical fiber-based schemes that function along the entire fiber length. Distributed optical fiber sensors are generally based on Rayleigh, Brillouin, and Raman scattering, and use various demodulation schemes, including optical time-domain reflectometry, optical frequency-domain reflectometry, and related schemes. Local external perturbations along the sensing fiber (such as temperature and strain) can be detected by variations in amplitude, frequency, polarization, or phase of the backscattered sensing light. Each technique has its own advantages and disadvantages in terms of spatial resolution (which defines how close two events can be detected separately), sensitivity (which is measure of system SNR and/or a deciding factor for maximum measurable length), and sensing resolution (which is a measure of the smallest parameter change that can be recorded).
FIGS. 8A-8B are drawings of a fiber optic acoustic sensor system in accordance with an embodiment of the present disclosure. In the embodiment illustrated in FIG. 8A-8B, wellbore 800 is being drilled by drill bit 806 attached to the downhole end of drill string 804. As shown in FIG. 8A, casing 802 is installed in the uphole portion of wellbore 800 and cement 810 fills the annulus between the wellbore and casing 802. Fiber optic cable 822 is installed in the cement 810, using the methods described in reference to FIGS. 1 to 3A-3D above. Specifically, fiber optic cable 822 is deployed from cable spool cartridge 820 attached to the exterior of casing 802 and using buoyancy device (not shown) attached to the upper end of fiber optic cable 822.
In an embodiment of the present disclosure, fiber optic cable 822 deployed as shown in FIG. 8A can be used for vibration monitoring of drilling operations. In the illustrated embodiment, a pulse of light can be transmitted down fiber optic cable 822 by a data acquisition unit at the surface (not shown). As the light travels down the fiber, light reflections known as backscatter can be detected, which are caused by tiny strain events within the fiber which in turn are caused by localized energy from acoustic signals 850 (shown in FIG. 8B). This backscattered light travels back up the fiber optic cable 822 towards the data acquisition unit where it is sampled. The time synchronization of the laser pulse, reflecting the phase, frequency, and amplitude of acoustic signals 850, allows the backscatter event to be accurately mapped to a distance along fiber optic cable 822 (and therefore to a point along the vertical length of the annulus). Detection and analysis of acoustic signals 850 can be utilized to monitor the effect of drilling on the mechanical integrity of cement 810. In addition, when combined with drilling parameters, such detection and analysis can also be utilized for predicting geological formations and detecting downhole events and problems, such as mechanical or other failures of the bottom-hole-assembly or other portion of drill string 804.
Patent Application
20220268117
