Distributed Fiber Optic Detection Using a Cement Implantation System

Abstract

DISTRIBUTED FIBER OPTIC DETECTION USING A CEMENTING DEPLOYMENT SYSTEM. Aspects of the technology in question relate to systems and methods for performing distributed measurements along a wellbore using distributed strain detection with a distributed fiber optic detection cable. Systems and methods are provided for utilizing a distributed fiber optic detection cable connected to a cementing tool to obtain distributed strain detection data along the wellbore. Distributed strain detection data are obtained along the wellbore from the distributed fiber optic detection cable. Distributed measurement pressure data are determined based on the distributed strain detection data received from the distributed fiber optic detection cable. A strain value is determined based on the distributed measurement pressure data and the distributed strain detection data.

Description

1 / 29 Distributed Fiber Optic Detection Using a Cement Implantation System CROSS-REFERENCE TO RELATED REQUESTS

[0001] This application claims the benefit of Non-Provisional Application U.S. 17 / 112,722, filed December 4, 2020, which claims the benefit of Provisional Application U.S. 62 / 969,017, filed January 31, 2020, the disclosure of which is incorporated herein by reference in its entirety. TECHNICAL FIELD

[0002] This disclosure generally refers to a cementing process, and more specifically (though not necessarily exclusively) to the performance of distributed measurements along a wellbore using a fiber optic sensing cable deployed during the cementing process. FUNDAMENTALS

[0003] During wellbore completion, the annular space between the wellbore wall and a casing string (or casing) can be filled with cement. This process is referred to as “cementing” the wellbore. A bottom plug can be inserted into the casing string after which cement can be pumped into the casing string. A top plug can be inserted into the wellbore after a desired quantity of cement has been injected. The top plug, cement, and bottom plug can be forced to the bottom of the well by injecting displacement fluid into the casing string.

[0004] The use of electrical pressure sensors at the bottom of the well allows for the detection of pressure changes within a wellbore. Fiber optic cables have also found application in monitoring and understanding the geological conditions within a wellbore. There is a need to accurately obtain bottomhole pressure and / or temperature to determine attributes such as flow rate distribution in wellbore boreholes. BRIEF DESCRIPTION OF THE DRAWINGS

[0005] FIG. 1 illustrates a system for preparing and distributing a cement mixture to a well borehole in accordance with aspects of the present disclosure. Petition 870220047449, dated 05 / 31 / 2022, page 41 / 80 2 / 29

[0006] FIG. 2A illustrates surface equipment that can be used in placing a cement composition in a wellbore according to aspects of the present disclosure.

[0007] FIG. 2B illustrates the placement of a cement composition in a wellbore annulus according to aspects of the present disclosure.

[0008] FIG. 3 illustrates an example schematic diagram of a system for performing distributed measurements along a wellbore using distributed strain detection with a fiber optic cable during a cementing process according to aspects of the present disclosure.

[0009] FIG. 4 illustrates an example of a process for performing distributed measurements along a wellbore using distributed strain detection with a fiber optic cable during a cementing process according to aspects of the present disclosure.

[0010] FIG. 5 illustrates an example of a computing device architecture that can be used to perform various steps, methods, and techniques disclosed in this document. DETAILED DESCRIPTION

[0011] Various forms of disclosure are discussed in detail below. While specific implementations are discussed, it should be understood that this is done for illustrative purposes only. One skilled in the relevant art will recognize that other components and configurations may be used without departing from the spirit and scope of disclosure.

[0012] Additional features and advantages of disclosure will be set forth in the following description and, in part, will be obvious from the description, or may be learned by practicing the principles disclosed in this document. The features and advantages of disclosure may be realized and obtained through the instruments and combinations particularly highlighted in the appended claims. These and other features of disclosure will become more evident from the following description and appended claims, or may be learned by practicing the principles set forth in this document.

[0013] It will be noticed that, for simplicity and clarity of illustration, where appropriate, reference numbers have been repeated among the different figures to indicate corresponding or analogous elements. Furthermore, numerous specific details are presented in order to provide a complete understanding of the embodiments described in this document. However, it will be understood by those skilled in the art that the embodiments described in this Petition 870220047449, dated 05 / 31 / 2022, page 42 / 80 3 / 29 of this document may be practiced without these specific details. In other cases, the methods, procedures, and components have not been described in detail so as not to obscure the relevant related feature being described. The drawings are not necessarily to scale, and the proportions of certain parts may be exaggerated to better illustrate details and features. The description should not be considered as limiting the scope of the embodiments described in this document.

[0014] As used in this document, “cement” is any type of material capable of being pumped to flow to a desired location and capable of settling into a solid mass at the desired location. “Cement paste” designates cement in its fluid state. In many cases, common calcium silicate hydraulic cement is suitable, such as Portland cement. Calcium silicate hydraulic cement includes a source of calcium oxide, such as burnt limestone, a source of silicon dioxide, such as burnt clay, and varying amounts of additives, such as sand, pozzolan, diatomaceous earth, iron pyrite, alumina, and calcium sulfate. In some cases, the cement may include polymer, resin, or latex, either as an additive or as the main constituent of the cement.The polymer may include polystyrene, ethylene / vinyl acetate copolymer, polymethyl methacrylate polyurethanes, polylactic acid, polyglycolic acid, polyvinyl alcohol, polyvinyl acetate, hydrolyzed ethylene / vinyl acetate, silicones, and combinations thereof. The cement may also include reinforcing fillers such as fiberglass, ceramic fiber, or polymer fiber. The cement may also include additives to improve or alter the properties of the cement, such as setting accelerators, setting retarders, antifoaming agents, fluid loss agents, weighting materials, dispersants, density reducing agents, formation conditioning agents, lost circulation materials, thixotropic agents, suspension aids, or combinations thereof.

[0015] The cement compositions disclosed in this document may directly or indirectly affect one or more components or pieces of equipment associated with the preparation, distribution, recapture, recycling, reuse and / or disposal of the disclosed cement compositions. For example, the disclosed cement compositions may directly or indirectly affect one or more mixers, related mixing equipment, slurry tanks, storage facilities or units, composition separators, heat exchangers, sensors, meters, pumps, compressors, and similar items used to generate, store, monitor, regulate and / or recondition the Petition 870220047449, dated 05 / 31 / 2022, page 43 / 80 4 / 29 exemplary cement compositions. The disclosed cement compositions may also directly or indirectly affect any support or distribution equipment used to transport the cement composition to a well or downhole site, such as, for example, any transport vessels, pipelines, pipelines, trucks, pipes and / or tubes used to move the cement composition from one location to another, any pumps, compressors or motors (e.g., surface or downhole) used to drive the cement compositions in motion, any valves or related joints used to regulate the pressure or flow rate of the cement compositions and any sensors (i.e., pressure and temperature), gauges and / or combinations thereof and the like.

[0016] The disclosed cement compositions may also directly or indirectly affect various downhole equipment and tools that may come into contact with the cement compositions, such as, but not limited to, well casing, wellbore liner, completion string, insertion strings, drill string, coiled tubing, flat cable, fixed cable, drill pipe, drill collar, mud motors, downhole motors and / or pumps, cement pumps, surface-mounted motors and / or pumps, centralizers, turbulators, scrapers, floats (e.g., shoes, collars, valves, etc.), logging tools and related telemetry equipment, actuators (e.g., electromechanical devices, hydromechanical devices, etc.), sliding gloves, production gloves, plugs, screens, filters, flow control devices (e.g., influx control devices, autonomous influx control devices, outlet flow control devices, etc.), couplings (e.g., electro-hydraulic wet connection, dry connection, inductive coupler, etc.), control lines (e.g., electrical, fiber optic, hydraulic, etc.), surveillance lines, drilling bits and reamers, sensors or distributed sensors, downhole heat exchangers, valves and corresponding actuation devices, tool seals, packers, cement plugs, bridge plugs, and other well isolation devices, or components, and the like.

[0017] In one aspect, a system includes a cementing tool positionable within a well casing string and a distributed temperature sensing (DTS) system. The cementing tool in several aspects may be a top plug. Petition 870220047449, dated 05 / 31 / 2022, p. 44 / 80 5 / 29 cementation or a top cementation plug dart. The DTS system may include a fiber optic cable coupled to the cementation tool; and a DTS interrogator positionable on a wellbore surface to transmit an optical signal through the fiber optic cable and determine from a reflected optical signal a plurality of temperatures along the fiber optic cable. The system may further include a fiber reel to distribute the fiber optic cable from a first end of the fiber optic cable in response to tension in the fiber optic cable as the cementation tool moves through the casing string behind a cement composition. This system may also include a processor in communication with the DTS system, which is configured to monitor the plurality of temperatures along the fiber optic cable while the cement composition cures.

[0018] In one aspect, the processor is configured to identify, based on the plurality of temperatures, one or more cement tops within the wellbore, a loss zone within the wellbore, or a first region of the wellbore that has more or less cement than a second region of the wellbore.

[0019] The processor can be configured to generate a notification in response to the monitoring of one or more unexpected temperatures based on one or more geothermal profiles and a wellbore design scheme. Alternatively, or in addition, the processor can be configured to generate a visualization based on the plurality of temperatures for display on a display device. The visualization may include at least one portion of a temperature contrast map. In some respects, at least one portion of the temperature contrast map is displayed comparatively with at least one portion of a wellbore design scheme. At least one portion of the temperature contrast map may be graphically superimposed on at least one portion of the design scheme or vice versa.

[0020] In one aspect, an artificial neural network (ANN) trained with borehole temperature readings including at least one known feature determines a correlation between at least one temperature and at least one known feature.

[0021] In another aspect, the system includes an additional fiber reel to distribute the fiber optic cable from a second end of the fiber optic cable. The fiber optic cable can be shielded or unshielded. The fiber reel, in some Petition 870220047449, dated 05 / 31 / 2022, p. 45 / 80 6 / 29 aspects, includes a drag device to prevent the fiber optic cable distribution in response to tension in the fiber optic cable from falling below a predefined value.

[0022] In one aspect, a method includes coupling a fiber optic cable to a cementing tool (e.g., cementing top plug or cementing top plug dart) positionable within a casing string of a wellbore, wherein the fiber optic cable is part of a DTS system further including a DTS interrogator positionable on a wellbore surface to transmit an optical signal through the fiber optic cable and to determine from a reflected optical signal a plurality of temperatures along the fiber optic cable. The method may also include coupling one end of the fiber optic cable to a fiber reel to dispense the fiber optic cable as the cementing tool moves through the casing behind a cement composition.The method may also include distributing the fiber optic cable along the fiber reel from one end of the fiber optic cable in response to tension in the fiber optic cable. Finally, the method may include monitoring multiple temperatures through the DTS system while the cement composition cures.

[0023] In several aspects, the fiber optic cable is coupled to a light source, such as a laser, to measure pressure, temperature, and strain distributions along the well. The Brillouin scattering phenomenon is a phenomenon caused by the transfer of energy via acoustic phonon when light is inserted into an optical fiber. The frequency difference between the inserted light and the Brillouin scattered light is referred to as the Brillouin frequency. The Brillouin frequency is proportional to the speed of sound in the optical fiber, and the speed of sound depends on the strain and temperature of the optical fiber. Thus, measuring the change in Brillouin frequency allows the measurement of the applied strain and / or temperature of the optical fiber. The Brillouin frequency changes with the pressure applied to the optical fiber. The Rayleigh scattering phenomenon is a phenomenon caused by light scattering due to the variation in the refractive index of an optical fiber.The frequency difference between the inserted light and the scattered Rayleigh light is the Rayleigh frequency. The Rayleigh frequency changes with the applied deformation and / or the temperature of the optical fiber.

[0024] In several respects, the fiber optic cable can be dispensed (or unwound) at one end by a reel (or spool) positioned close to the tool. Petition 870220047449, dated 05 / 31 / 2022, pp. 46 / 80 7 / 29 Cementing. An additional reel can be positioned near the wellbore surface and can also unwind additional lengths of fiber optic cable. The fiber optic cable can be a sacrificial cable that remains inside the well until it is ultimately destroyed during well operations, for example, during stimulation.

[0025] These illustrative examples are given to introduce the reader to the general subject matter discussed herein and are not intended to limit the scope of the concepts disclosed. The following sections describe various additional features and examples with reference to the figures, in which similar numbers indicate similar elements and directional descriptions are used to describe the illustrative aspects but, like the illustrative aspects, should not be used to limit the present disclosure.

[0026] With reference now to FIG. 1, a system that can be used in cementing operations will now be described. FIG. 1 illustrates a system 2 for preparing a cement mix and distributing it to a wellbore according to certain embodiments. As shown, the cement mix can be mixed in mixing equipment 4, such as a jet mixer, recirculation mixer or batch mixer, for example, and then pumped by means of pumping equipment 6 to the wellbore. In some embodiments, the mixing equipment 4 and the pumping equipment 6 can be arranged in one or more cement trucks, as will be evident to those skilled in the art. In some embodiments, a jet mixer can be used, for example, to continuously mix the mix, including water, as it is being pumped to the wellbore.

[0027] An example of a technique and system for placing a cement mix in an underground formation will now be described with reference to Figures 2A and 2B. FIG. 2A illustrates the surface equipment 10 that can be used in placing a cement mix according to certain embodiments. It should be noted that while FIG. 2A generally represents a land-based operation, those skilled in the art will readily recognize that the principles described in this document are equally applicable to subsea operations employing floating or sea-based platforms without departing from the scope of disclosure. As illustrated by FIG. 2A, the surface equipment 10 may include a cementing unit 12, which may include one or more cement trucks. The cementing unit 12 may include mixing equipment 4 and pumping equipment 6 (per Petition 870220047449, dated 05 / 31 / 2022, pp. 47 / 80 8 / 29 example, FIG. 1) as will be evident to those generally skilled in the art. The cementing unit 12 can pump a cement composition 14 through a feed pipe 16 and to a cementing head 18 which transmits the cement composition 14 to the bottom of the well.

[0028] Returning now to FIG. 2B, the cement composition 14 can be placed in an underground formation 20 according to exemplary embodiments. As illustrated, a wellbore 22 can be drilled into the underground formation 20. While the wellbore 22 is generally represented as extending vertically into the underground formation 20, the principles described in this document are also applicable to wellbores extending at an angle through the underground formation 20, such as horizontally and inclined drilled wellbores. As illustrated, the wellbore 22 comprises walls 24. In the illustrated embodiments, a surface casing 26 has been inserted into the wellbore 22. The surface casing 26 can be cemented into the walls 24 of the drilled wellbore 22 by the cement sheath 28. In the illustrated embodiment, one or more additional conduits (e.g., intermediate casing, production casing, liners, etc.)), shown here as casing 30, can also be disposed in wellbore 22. As illustrated, there is a wellbore annulus 32 formed between the casing 30 and the wellbore walls 24 and / or the surface casing 26. One or more centering devices 34 can be attached to the casing 30, for example, to center the casing 30 in wellbore 22 before and during the cementing operation.

[0029] With continued reference to FIG. 2B, cement composition 14 can be pumped into the interior of casing 30. Cement composition 14 can be allowed to flow inside casing 30 through casing shoe 42 at the bottom of casing 30 and upward around casing 30 into the wellbore annulus 32. Cement composition 14 can be allowed to settle in the wellbore annulus 32, for example, to form a cement sheath that supports and positions casing 30 in the wellbore 22. Although not illustrated, other techniques can also be used for the introduction of cement composition 14. As an example, reverse circulation techniques can be used which include introducing cement composition 14 into the underground formation 20 through the wellbore annulus 32 instead of through casing 30. Petition 870220047449, dated 05 / 31 / 2022, pp. 48 / 80 9 / 29

[0030] When introduced, the cement composition 14 can displace other fluids 36, such as drilling fluids and / or spacer fluids, which may be present inside the casing 30 and / or in the wellbore annulus 32. At least a portion of the displaced fluids 36 can exit the drilled wellbore annulus 32 by means of a flow line 38 and be deposited, for example, in one or more retention wells 40 (e.g., a mud well), as shown in FIG 2A.

[0031] Referring again to FIG. 2B, a bottom plug 44 can be introduced into the casing 30 ahead of the cement composition 14, for example, to separate the cement composition 14 from fluids 36 that may be inside the casing 30 before cementing. After the bottom plug 44 reaches the ground collar 46, a diaphragm or other suitable device ruptures to allow the cement composition 14 through the bottom plug 44. In FIG. 2B, the bottom plug 44 is shown in the ground collar 46. In the illustrated embodiment, an upper plug 48 can be introduced into the wellbore 22 behind the cement composition 14. The upper plug 48 can separate the cement composition 14 from a displacement fluid 53 and also push the cement composition 14 through the bottom plug 44.

[0032] FIG. 3 is a schematic diagram of a system 100 for performing distributed measurements along a well 102 using distributed strain detection with a fiber optic cable 122 during a cementing process. The system 100 may include a wellbore 102 with a casing string 104 extending from the surface 106 through the wellbore 102. A preventer assembly 107 (“BOP”) may be positioned above a wellhead 109 at the surface 106. The wellbore 102 extends through several earth strata and may have a substantially vertical section 108. In some aspects, the wellbore 102 may also include a substantially horizontal section. The casing string 104 may include multiple casing tubes 110 coupled end-to-end by casing collars 112. In some aspects, the casing tubes 110 are approximately thirty feet long.The substantially vertical section 108 may extend / through an underground formation containing rock or hydrocarbon 114.

[0033] A cementing tool, for example, a cement plug 116, can be positioned at the bottom of the well in the casing string 104. The cement plug 116 can be Petition 870220047449, dated 05 / 31 / 2022, pp. 49 / 80 10 / 29 an upper cement plug that is inserted into the casing string 104 after a desired quantity of cement 117 has been injected into the casing string 104. In some respects, a cement plugging dart may be used in place of the cement plug 116. The cement plug 116 may be forced to the bottom of the well by injecting surface displacement fluid 106. A lower cement plug may be positioned below the cement 117 and may be forced to the bottom of the well until it rests on a floating collar at the bottom of the casing string 104. The cement plug 116 may be forced downhole until it contacts the lower cement plug. The cement plug 116 may force the cement 117 downhole until it breaks the lower cement plug and is forced out of a casing string shoe 104.The cement 117 can then flow out of the casing string 104 and into the annular space 119 of the wellbore 102 as in a direct cementing process.

[0034] The cement plug 116 can be coupled to a locating device, such as the magnetic pickup coil 118, which can generate a voltage in response to a change in a surrounding magnetic field. In one example, the locating device may be a magnetic pickup coil 118. In other examples, a piezoelectric sensor or other suitable locating device may be used by the system 100. The magnetic pickup coil 118 may include a permanent magnet with a coil wound around it. The casing tubes 110 can each emit a magnetic field. Each casing collar 112 can emit a magnetic field that is different from the magnetic field emitted by the casing tubes 110, which can be joined by the casing collar 112. The change in the magnetic field between the casing collars 112 and the casing tubes 110 can be detected by the magnetic pickup coil 118 of the system 100.The magnetic pickup coil 118 of system 100 can generate a voltage in response to the change in the surrounding magnetic field when the magnetic pickup coil 118 passes through a sheath collar 112. The voltage generated by the magnetic pickup coil 118 can be proportional to the speed of the magnetic pickup coil 118 as the magnetic pickup coil 118 passes through the sheath collar 112. In some respects, the magnetic pickup coil 118 of system 100 can travel between approximately 10 feet per second and approximately 30 feet per second. Petition 870220047449, dated 05 / 31 / 2022, pages 50 / 80 11 / 29

[0035] The magnetic pickup coil 118 of system 100 can be coupled to a light source, for example, a light-emitting diode (LED) 120. The voltage generated by the magnetic pickup coil 118 can momentarily energize the LED 120, which can be coupled to the magnetic pickup coil 118. The LED 120 can emit a light pulse (for example, an optical signal) in response to the voltage generated by the pickup coil 118. The LED 120 of system 100 can transmit the light pulse to a receiver 124 positioned on the surface 106. In some respects, the LED 120 can operate at a wavelength of 1300 nm and can minimize Rayleigh transmission losses and coil bend-induced and hydrogen-induced optical power losses. In some respects, a high-speed laser diode or other optical sources can be used in place of the 120 LED, and various other optical wavelengths can be used.For example, wavelengths from about 850 nm to 2100 nm can make use of the low-transmission wavelength optical bands in common single-mode and multimode fused silica fibers.

[0036] The LED 120 drive circuit of system 100 may require a minimum voltage generated by the magnetic pickup coil 118 to complete the circuit and generate the light pulse. In some respects, the LED 120 drive circuit may be bypassed with power from a battery or other power source. The angled LED 120 drive circuit may require less voltage to be induced in the magnetic pickup coil 118 to complete the circuit and generate the light pulse. The angled LED 120 drive circuit may allow small changes in the magnetic field detected by the magnetic pickup coil 118 to generate sufficient voltage to power the LED 120. In some respects, the biased LED 120 drive circuit may allow the magnetic pickup coil 118, traveling at a low speed, to pass through a coating collar 112 and generate sufficient voltage to complete the LED 120 circuit, thus emitting a light pulse.In some respects, a light source can be positioned close to surface 106 and can transmit an optical signal hole down to determine the location of a collar locator within the casing column 104.

[0037] The light pulse generated by LED 120 of system 100 can be transmitted to the receiver positioned on the surface 106 using a distributed fiber optic sensor cable 122. The receiver 124 can be an optical receiver, for example, the receiver 124 can be a photodetector. Petition 870220047449, dated 05 / 31 / 2022, pp. 51 / 80 12 / 29 which can convert optical signals into electrical signals. In some respects, the receiver 124 of system 100 can count the number of light pulses received through the fiber optic cable 122. The number of light pulses received by the receiver 124 can indicate the number of casing collars 112, the magnetic pickup coil 118, and the plug 116 that have passed. The wellbore 102 can be mapped on the surface based on the number of casing pipes 110 positioned within the wellbore 102 and their respective lengths. The number of casing collars 112 and the cement plug 116 that have passed can indicate the position of the cement plug 116 within the wellbore 102. In some respects, the receiver 124 can transmit information to the magnetic pickup coil 118 or other collar locator through the fiber optic cable 122 of system 100.

[0038] In another example, system 100 may include a light source which may be a laser 113 positioned on surface 106 near BOP 107. The laser 113 may be coupled to the fiber optic cable 122 which may be dispensed at one end by the upper reel 132. The upper reel 132 may be positioned on surface 106 near BOP 107. In some respects, the laser 113 and the upper reel 132 may be positioned elsewhere on surface 106 or within the wellbore 102.

[0039] The laser 113 of the system 100 may be a high-repetition pulse laser or other suitable light source. The laser 113 of the system 100 may also generate an optical signal, for example, a series of light pulses that are transmitted through the fiber optic cable 122. The cement cap 116 of the system 100 may be coupled to the reel 138 and the magnetic pickup coil 118. A modulation device (for example, a pendulum switch) may be coupled to the magnetic pickup coil 118 near one end of the fiber optic cable 122. The modulation device may modulate the optical signal (for example, light pulses) generated by the laser 113 in response to a voltage generated by the magnetic pickup coil 118 as it passes through a sheath collar 112. In some respects, a piezoelectric sensor or other suitable modulation device may be used to modulate the optical signal of the laser 113.In some respects, the modulation device can modulate, for example, but not limited to, the frequency, amplitude, phase, or other suitable characteristic of the optical signal. The optical signal generated by laser 113 can travel the length of the fiber optic cable 122 and reach a lower end of the fiber optic cable 122 near the lower reel 138. Petition 870220047449, dated 05 / 31 / 2022, pp. 52 / 80 13 / 29

[0040] The receiver 124 of system 100 can be communicatively coupled to a computing device 128 located away from the wellbore 102 by a communication link 130. The communication link 130 can be a wireless communication link. The communication link 130 can include wireless interfaces such as IEEE 802.11, Bluetooth, or radio interfaces for accessing cellular telephone networks (e.g., transceiver / antenna for accessing a CDMA, GSM, UMTS, or other mobile communications network). In some respects, the communication link 130 can be wired. A wired communication link can include interfaces such as Ethernet, USB, IEEE 1394, or a fiber optic interface. The receiver 124 of system 100 can transmit information related to the optical signal, for example, but not limited to, the count of light pulses, the time the light pulse arrived, or other information, to the computing device 128.In some respects, the receiver 124 of system 100 can be coupled to a transmitter that communicates with the computing device 128.

[0041] The strain value based on distributed measurement pressure data from communication link 130 can be received by a computing device 128 through a network interface with a compatible communication link 130. In some respects, the computing device 128 of system 100 can use the interface to communicate with one or more networks, such as a local area network (LAN) and / or a wide area network (WAN), such as the Internet. The computing device 128 of system 100 can also include a processor to process the received distributed measurement pressure data. The processor can be incorporated, without limitation, as a microprocessor, application-specific integrated circuit (ASIC), digital signal processor (DSP), field-programmable gate array (FPGA), or the like. The processor can execute instructions stored in a storage device to perform aspects of the methods described in this document.The storage device can also be used to store one or more profiles, which can be incorporated as any data structure suitable for representing received and / or processed data. In one aspect, the computing device 128 may further include a user interface, such as a graphics card, to display graphics and / or text on a display device, such as a computer monitor. The user interface may display pressure and temperature based on the determined strain value. Petition 870220047449, dated 05 / 31 / 2022, pp. 53 / 80 14 / 29

[0042] The 122 fiber optic cable of system 100 that transmits the light pulse to / from LED 120 to receiver 124 may be an unshielded fiber. Unshielded fiber may include a fiber core and cladding and a thin primary buffer jacket, but without an outer jacket or secondary airtight buffer to minimize fiber diameter to increase the fiber length capacity of a given return reel or spool. In some respects, the 122 fiber optic cable of system 100 may be a shielded fiber. Shielded fiber may include a fiber core, a cladding, a thin primary buffer that encloses an outer jacket or secondary airtight buffer. The inclusion of the outer jacket or secondary airtight buffer may increase the diameter of the 122 fiber optic cable. The 122 fiber optic cable may be a multimode or single-mode fiber optic cable. The 122 fiber optic cable may include one or more optical fibers.Fiber optic cable 122 may be a sacrificial cable that is not recovered from well 102, but instead remains in well 102 until it is destroyed. For example, fiber optic cable 122 may be destroyed during wellbore stimulation 102.

[0043] The fiber optic cable 122 of system 100 can also be dispensed from an upper reel or spool 132 positioned inside the wellbore 102 near the surface 106 when the cement plug 116 is forced to the bottom of the well. In some respects, the upper reel 132 can be positioned at the surface 106, for example, the upper reel 132 can be positioned near the preventer assembly 107. The upper reel 132 can be fixed inside the wellbore 102 by a fastening device, for example, by spring-loaded cam feet 136 or other suitable fastening mechanisms. The upper reel 132 of system 100 can have a near-zero tension return force that can allow the fiber optic cable 122 to be distributed when there is tension in the fiber optic cable 122.

[0044] The fiber optic cable 122 of system 100 can still be tensioned and pulled along with the displacement fluid that is injected into the casing string 104 to move the cement plug 116. The upper reel 132 of system 100 can dispense additional lengths of fiber optic cable 122 when the fiber optic cable 122 is tensioned by the displacement fluid injected into the well 102. In some respects, the fiber optic cable 122 of system 100 can unwind the upper reel 132 at the same rate as the flow of displacement fluid. The upper reel 132 can prevent the fiber optic cable 122 from breaking or becoming damaged. Petition 870220047449, dated 05 / 31 / 2022, pp. 54 / 80 15 / 29 becomes damaged as fiber optic cable 122 and plug 116 move at the bottom of the well.

[0045] The fiber optic cable 122 of system 100 may also be wound and distributed from a lower reel or spool 138 positioned close to the magnetic pickup reel 118. The lower reel 138 may include a drag device 139. The drag device 139 may allow the lower reel 138 to distribute the fiber optic cable 122 only when a predefined tension on the fiber optic cable 122 is reached. The return of the lower reel 138 may prevent the fiber optic cable 122 from breaking or becoming damaged as the fiber optic cable 122 and the cement plug 116 move at the bottom of the well. The upper reel 132 and the lower reel 138 may hold greater lengths of unshielded fiber optic cable than shielded fiber optic cable. Although FIG.3 represents the lower coil 138 positioned below the LED 120 and the magnetic pickup coil 118; in some aspects, the lower coil 138 may be positioned elsewhere relative to the LED 120 and the magnetic pickup coil 118 of system 100.

[0046] With reference to FIG. 3, the system 100 may still include permanently installed sensors. The sensors may include fiber optic cables 122 being cemented in place in the annular space between the casing string 104 and the formation 114, or fiber optic cables 122 may be positioned within the casing string 104, as shown in FIG. 3. The fiber optic cables 122 may also include fiber optic lines, fiber optic tubes, waveguides, optical waveguides, or any other fiber suitable for the intended purpose and understood by a person skilled in the art. Other types of permanent sensors may include surface and downhole pressure sensors, where the pressure sensors may be capable of collecting data at rates up to 2,000 Hz or even higher.

[0047] The 122 fiber optic cables of the 100 system may house one or more optical fibers, and the optical fibers may be single-mode fibers, multi-mode fibers, or a combination of single-mode and multi-mode optical fibers. The system connected to the optical fibers may include DTS systems, distributed acoustic sensing (DAS) systems, distributed strain sensing (DSS) systems, quasi-distributed sensing systems where multiple single-point sensors are distributed along an optical fiber / cable, or sensing systems. Petition 870220047449, dated 05 / 31 / 2022, pp. 55 / 80 16 / 29 single point where the sensors are located at the end of the cable. For each of the 122 optical fibers, Brillouin measurement and Coherent Rayleigh measurement(s) are performed on the ground surface to obtain Brillouin and Rayleigh frequency shift distributions or backscatter-based interferometric phase shift along the optical fibers. From these Brillouin frequency shift and Rayleigh-based interferometric phase shift distributions, pressure, temperature, and strain distributions along the 122 optical fiber cable can be determined simultaneously.

[0048] System 100 can operate using various detection principles. One example includes a DTS system based on inelastic Raman scattering with comparison of Stokes and Antistokes signal intensities to derive the localized fiber temperature. Another example includes a system based on optical phase shift detection, such as a DAS system, which is based on interferometric detection principles using a highly coherent laser and homodyne or heterodyne detection techniques, where the system can detect phase and / or optical signal intensity changes due to constructive or destructive interference along said fibers, due to changes in the optical path length from temperature disturbances or strain. Another example includes a strain detection system, such as a DSS using integrated dynamic strain measurements based on interferometric sensors or static strain detection measurements using Brillouin scattering.Brillouin-based DSS systems detect strain and temperature through inelastic scattering, where an acoustic phonon vibration is generated near 11 GHz in silica optical fiber and can be demodulated to measure phonon frequency shift, which is a function of strain and / or temperature. Other examples include quasi-distributed sensors based on Fiber Bragg Gratings (FBGs) where a wavelength shift is detected, or multiple FBGs or multiple fibers are used to form Fabry-Perot, Mach-Zehnder, Michelson, or Sagnac type interferometric sensors for phase-based detection, or single-point fiber optic sensors based on Fabry-Perot or FBG, or intensity-based sensors.

[0049] Electrical sensors can be pressure sensors based on quartz crystal type sensors or sensors based on vibrating wire strain gauges or other commonly used sensing technologies. Pressure sensors, whether optical or electrical, can Petition 870220047449, dated 05 / 31 / 2022, pages 56 / 80 17 / 29 can be housed in dedicated gauge mandrels or mounted outside the 104 casing string in various configurations for downhole deployment or conventionally deployed in the surface wellhead or flowlines.

[0050] Several hybrid approaches where single-point or quasi-distributed or distributed fiber optic sensors are mixed, for example, with electrical sensors, are also anticipated. The 122 fiber optic cable will then include both fiber optics and electrical conductors.

[0051] The DTS system may include a receiver 124 which is a DTS interrogator, which transmits round-trip laser pulses approximately 2 meters long (equivalent to a round-trip delay time of 10 seconds) to the fiber optic cable 122 for a one-way spatial resolution of 1 m. By analyzing the reflected light using techniques such as Raman scattering, the DTS interrogator is able to calculate distributed measurement pressure data from distributed strain detection data (analyzing the power or intensity of the reflected light) and also the event location (measuring the time it takes for the backscattered light to return from its initial laser pulse injection time at t = 0). The strain values ​​based on the distributed measurement pressure data are recorded along the fiber optic cable 122 as a continuous profile.In one aspect, the DTS interrogator can transmit temperature data to multiple points along the fiber optic cable 122 using the communication link 130 described earlier.

[0052] Measurements from a DTS system, for example, can be used to determine fluid entry points in the treatment plant, as well as the fact that surface fluids are likely to be cooler than formation temperatures. Measurements in observation wells can be used to determine fluid communication between the treatment plant and the observation well, or to determine formation fluid movement.

[0053] DAS data can be used by system 100 to determine fluid allocation in real time as acoustic noise is generated when fluid flows through casing string 104 and through boreholes into formation 114. Phase and intensity-based interferometric sensing systems are sensitive to temperature and mechanical vibrations as well as acoustically induced ones. DAS data can be converted from time series data to frequency domain data using Fast Fourier Transforms (FFTs), and other transformations such as wavelet transforms can also be used to Petition 870220047449, dated 05 / 31 / 2022, pages 57 / 80 18 / 29 generate different representations of the data. Various acoustic or vibrational frequency ranges can be used to fingerprint or derive characteristic acoustic spectral signatures for different wellbore measurement parameters and where, for example, low frequency signal changes can be attributed to formation deformation changes or fluid motion and other frequency ranges can be indicative of fluid or gas motion.

[0054] Various filtering techniques can be applied by the 100 system to generate event indicators that may be of interest. Indicators may include formation motion due to growing natural fractures, formation stress changes during fracturing operations (this effect may also be called stress shading), fluid infiltration during fracturing operations (as formation motion can force fluid and observe the well and this can be detected), fracture fluid flow, and fluid and proppant flow from fracturing strikes. Each indicator may have a characteristic signature in terms of frequency and / or amplitude content and / or time-dependent behavior, and these indicators may be present in other data types and are not limited to DAS data.

[0055] DAS systems can also be used by system 100 to detect various seismic events where increasing stress fields and / or fracture networks generate microseismic events or where drilling change events can be used to determine the travel time between horizontal wells and this information can be used stage-by-stage to determine changes in travel time as formation 114 is fractured and filled with fluid and proppant. DAS systems can also be used with surface seismic sources to generate vertical seismic profiles before, during and after a fracturing job to determine the effectiveness of the fracturing job as well as to determine the effectiveness of production.

[0056] DSS data can be generated by the 100 system using various approaches, and static strain data can be used to determine absolute strain changes over time. Static strain data are often measured using Brillouin-based systems or quasi-distributed strain data from FBG-based systems. Static strain can also be used to determine the supported fracture volume by observing deviations in strain data from a baseline of Petition 870220047449, dated 05 / 31 / 2022, pages 58 / 80 19 / 29 strain measured before fracturing a stage. It may also be possible to determine formation properties such as permeability, poroelastic responses, and leakage rates based on the change in strain versus time and the rate at which the strain changes over time. Dynamic strain data can be used in real time to detect fracture growth through an appropriate inversion model, and appropriate actions such as dynamic changes in fluid flow rates in the treatment well, addition of diverters or chemicals in the fracturing fluid, or changes in proppant concentrations or types can then be used to mitigate detrimental effects.

[0057] Fiber Bragg Grating (FBG) based systems can also be used for a variety of different measurements. FBGs are partial reflectors that can be used as temperature and strain sensors, or they can be used to make various interferometric sensors with very high sensitivity. FBGs can be used to make point sensors or quasi-distributed sensors where these FBG-based sensors can be used independently or with other types of fiber optic-based sensors. FBGs can be fabricated on an optical fiber at a specific wavelength, and other systems such as DAS, DSS, or DTS systems can operate at different wavelengths on the same fiber and measure different parameters simultaneously with FBG-based systems using Wavelength Division Multiplexing (WDM).

[0058] System 100 sensors can be placed in the treatment well or monitoring well(s) to measure well communication. Pressure, rate, proppant concentration, diverters, fluids, and chemicals in the treatment well can be altered to modify the hydraulic fracturing treatment. These changes can impact formation responses in several different ways. Stress fields can change, and this can generate microseismic effects that can be measured with DAS systems and / or single-point seismic sensors such as geophones. Fracture growth rates can change, and this can generate changes in measured microseismic events and event distributions over time, or changes in deformation measured using the low-frequency portion or the DAS signal or Brillouin-based detection systems. Pressure changes due to poroelastic effects can be measured in the monitoring well.Pressure data can be measured at the treatment well. Petition 870220047449, dated 05 / 31 / 2022, pp. 59 / 80 20 / 29 and correlated with fracture formation responses. Various changes in treatment rates and pressure can generate events that may be correlated with fracture growth rates.

[0059] Multiple measurements can be combined by the 100 system to determine adjacent well communication, and this information can be used to alter the hydraulic fracturing treatment schedule to generate the desired results.

[0060] Having disclosed some example system components and concepts, the disclosure now turns to FIG. 4, which illustrates example method 400 for making distributed measurements along a well using distributed strain detection with a fiber optic cable during a cementing process. The steps highlighted here are exemplary and can be implemented in any combination thereof, including combinations that exclude, add, or modify certain steps.

[0061] In step 402, method 400 may include using a distributed fiber optic sensing cable connected to a cementing tool positioned in a wellbore. The distributed fiber optic sensing cable may be configured to obtain distributed strain sensing data along the wellbore. The cementing tool, for example, a cement plug, may be positioned at the bottom of the well in the casing string. The cement plug may be a top cement plug that can be inserted into the casing string after a desired amount of cement has been injected into the casing string. In some examples, a dart to plug a cement plug may be used in place of the cement plug.

[0062] In some implementations, the fiber optic cable connected to the cementing tool can be forced to the bottom of the well by injecting surface displacement fluid. A light source, such as a laser or LED, can move to the bottom of the well with the cementing tool. The LED can generate a light pulse, which can be transmitted to the receiver on the surface via the fiber optic cable. In some examples, a distributed sensor comprises a fiber optic cable and an associated interrogator unit to send and receive optical signals through the fiber optic cable.

[0063] In step 404, method 400 may include receiving strain detection data distributed along the well of the distributed fiber optic detection cable. The Petition 870220047449, dated 05 / 31 / 2022, pp. 60 / 80 21 / 29 Distributed strain detection data can be based on backscattered optical signals. Light enters the fiber optic cable above the well, and a backscattered signal is measured by components on the surface. The backscattered light signal can contain information about strain changes and location information indicating where along the fiber optic cable they occurred.

[0064] In step 406, method 400 can include determining distributed measurement pressure data based on distributed strain detection data received from the distributed fiber optic cable. It can be observed that Rayleigh backscattered light, Raman backscattered light, and Brillouin backscattered light are observed. A frequency analysis can be performed for backscattered light. The backscattered light can be recorded along the length of the fiber optic cable. The amplitude and frequency shift of the Brillouin peaks relative to the Rayleigh peaks can be measured from which the strain distributions along the fiber optic cable can be determined. The frequency shifts of Brillouin and Rayleigh can be used to obtain measurement values ​​for strain.

[0065] In step 408, method 400 may include determining a strain value based on distributed measurement pressure data and distributed strain detection data. A Brillouin frequency shift may be caused by strain applied to the fiber optic cable. The applied pressure can be measured by analyzing the frequency shift of the fiber optic cable. Temperature distributions can also be measured by means of Rayleigh frequency shift or Brillouin frequency shift. Pressure and temperature distributions can be provided on a display or user interface of a computing device.

[0066] FIG. 5 illustrates an example of a 500 computing device architecture that can be employed to perform various steps, methods, and techniques disclosed in this document. The various implementations will be evident to those skilled in the art when practicing the present technology. Persons ordinarily skilled in the art will also readily realize that other system implementations or examples are possible.

[0067] As noted above, FIG. 5 illustrates an example of a computing device architecture 500 of a computing device that can implement the various technologies Petition 870220047449, dated 05 / 31 / 2022, pages 61 / 80 22 / 29 and techniques described in this document. The components of the computing device architecture 500 are shown in electrical communication with each other using a connection 505, such as a bus. The example computing device architecture 500 includes a processing unit (CPU or processor) 510 and a connection to the computing device 505 that couples various computing device components, including computing device memory 515, such as read-only memory (ROM) 520 and random-access memory (RAM) 525, to the processor 510.

[0068] The computing device architecture 500 may include a high-speed memory cache directly connected to, in immediate proximity to, or integrated as part of the processor 510. The computing system architecture 500 may copy data from memory 515 and / or storage device 530 to the cache 512 for fast access by the processor 510. In this way, the cache may provide a performance boost that prevents the processor 510 from lagging while waiting for data. These and other modules may control or be configured to control the processor 510 to perform various actions. Other computing device memory 515 may also be available for use. Memory 515 may include several different types of memory with different performance characteristics.The 510 processor can include any general-purpose processor and a hardware or software service, such as service 1 532, service 2 534, and service 3 536 stored in storage device 530, configured to control the 510 processor, as well as a special-purpose processor where software instructions are incorporated into the processor design. The 510 processor can be a standalone system containing multiple cores or processors, a bus, memory controller, cache, etc. A multi-core processor can be symmetric or asymmetric.

[0069] To enable user interaction with the computing device 500, an input device 545 may represent any number of input mechanisms, such as a microphone for speech, a touch screen for gesture or graphic input, keyboard, mouse, motion input, speech, and so forth. An output device 535 may also be one or more of a number of output mechanisms known to those skilled in the art, such as a monitor, projector, television, speaker device, etc. In some cases, multimodal computing devices may allow a user to provide multiple types of input to themselves. Petition 870220047449, dated 05 / 31 / 2022, pages 62 / 80 23 / 29 communicate with the computing device architecture 500. The 540 communication interface can generally govern and manage user input and output from the computing device. There is no restriction regarding operation in any particular hardware arrangement, and therefore the basic features described in this document can be easily replaced by improved hardware or firmware arrangements as they are developed.

[0070] Storage device 530 is non-volatile memory and may be a hard disk or other types of computer-readable media that can store data accessible by a computer, such as magnetic cassettes, flash memory cards, solid-state memory devices, digital versatile disks, cartridges, random access memories (RAMs) 525, read-only memory (ROM) 520, and hybrids thereof. Storage device 530 may include services 532, 534, 536 to control processor 510. Other hardware or software modules are contemplated. Storage device 530 may be connected to the computing device connection 505.In one aspect, a hardware module that performs a specific function may include the software component stored on a computer-readable medium in connection with the necessary hardware components, such as the processor 510, connector 505, output device 535, and so on, to perform the function.

[0071] For clarity of explanation, in some cases, the present technology may be presented as including individual functional blocks, including functional blocks comprising devices, device components, steps or routines, in a method embodied in software or combinations of hardware and software.

[0072] In some embodiments, computer-readable storage devices, media and memories may include a cable or wireless signal containing a bit stream and the like. However, when mentioned, computer-readable non-transient storage media expressly exclude media such as energy, carrier signals, electromagnetic waves and signals per se.

[0073] Methods according to the examples described above can be implemented using computer-executable instructions that are stored or otherwise available from computer-readable media. Such instructions may include, for example, instructions and data that cause or otherwise configure a general-purpose computer, Petition 870220047449, dated 05 / 31 / 2022, pages 63 / 80 24 / 29 A special-purpose computer or processing device used to perform a specific function or group of functions. Portions of the computer resources used may be accessible via a network. Computer-executable instructions can be, for example, binary, intermediate format instructions such as set language, firmware, source code, etc. Examples of computer-readable media that can be used to store instructions, information used, and / or information created during the methods described include magnetic or optical disks, flash memory, USB devices supplied with non-volatile memory, network storage devices, and so on.

[0074] Devices implementing methods according to these disclosures may include hardware, firmware, and / or software and may assume any of a variety of form factors. Typical examples of such form factors include laptops, smartphones, small form factor personal computers, personal digital assistants, rack-mounted devices, standalone devices, and so forth. The functionality described in this document may also be incorporated into peripheral or add-on cards. Such functionality may also be implemented on a circuit board between different chips or different processes running on a single device, by way of further example.

[0075] Instructions, means for transmitting such instructions, computing resources for executing them, and other structures for supporting such computing resources are example means for providing the functions described in this disclosure.

[0076] In the preceding description, aspects of the application are described with reference to specific embodiments thereof, but those skilled in the art will recognize that the application is not limited to them. Thus, although illustrative embodiments of the application have been described in detail in this document, it should be understood that the concepts disclosed may be incorporated and employed in other ways, and that the appended claims are intended to be interpreted to include such variations, except as limited by the state of the art. Various features and aspects of the subject described above may be used individually or in combination. Furthermore, the embodiments may be used in any number of environments and applications beyond those described in this document, without departing from the broader spirit and scope of the descriptive report. The descriptive report and drawings should therefore be considered illustrative and not restrictive.For illustrative purposes, the methods have been described in a specific order. Petition 870220047449, dated 05 / 31 / 2022, pages 64 / 80 25 / 29 particular. It should be noted that in alternative modalities, the methods may be performed in a different order than that described.

[0077] Where components are described as being “configured to” perform certain operations, such configuration may be achieved, for example, by designing electronic circuits or other hardware to perform the operation, by programming programmable electronic circuits (e.g., microprocessors or other suitable electronic circuits) to perform the operation, or any combination thereof.

[0078] The various illustrative logic blocks, modules, circuits, and algorithm steps described in connection with the examples disclosed in this document may be implemented as electronic hardware, computer software, firmware, or combinations thereof. To clearly illustrate this interchangeability of hardware and software, various illustrative components, blocks, modules, circuits, and steps have been described above, generally in terms of their functionality. Whether this functionality is implemented as hardware or software depends on the particular application and the design constraints imposed on the overall system. Skilled craftsmen may implement the described functionality in various ways for each specific application, but such implementation decisions should not be interpreted as causing a deviation from the scope of the present application.

[0079] The techniques described herein may also be implemented in electronic hardware, computer software, firmware, or any combination thereof. These techniques may be implemented in any of a variety of devices, such as general-purpose computers, wireless communication device sets, or multi-purpose integrated circuit devices, including application in wireless communication device sets and other devices. Any features described as modules or components may be implemented together in an integrated logic device or separately as distinct but interoperable logic devices. If implemented in software, the techniques may be performed, at least in part, by a computer-readable data storage medium comprising program code including instructions that, when executed, perform one or more of the methods, algorithms, and / or operations described above.Computer-readable data storage media can be part of a computer program product, which may include packaging materials. Petition 870220047449, dated 05 / 31 / 2022, pages 65 / 80 26 / 29

[0080] Computer-readable media may include memory or data storage media, such as random access memory (RAM), such as synchronous dynamic random access memory (SDRAM), read-only memory (ROM), non-volatile random access memory (NVRAM), electrically erasable programmable read-only memory (EEPROM), FLASH memory, magnetic or optical data storage media and the like. The techniques may additionally, or alternatively, be implemented, at least in part, by a computer-readable communication medium that carries or communicates the program code in the form of instructions or data structures and that can be accessed, read and / or executed by a computer as propagated signals or waves.

[0081] Other forms of dissemination can be practiced in networked computing environments with many types of computer system configurations, including personal computers, portable devices, multiprocessor systems, microprocessor-based or programmable consumer electronics, network PCs, minicomputers, mainframe computers, and the like. These forms can also be practiced in distributed computing environments, where tasks are performed by local and remote processing devices that are connected (by wired links, wireless links, or a combination thereof) through a communications network. In a distributed computing environment, program modules can be located on both local and remote memory storage devices.

[0082] In the above description, terms such as “upper,” “upward,” “lower,” “downward,” “above,” “below,” “hole below,” “hole above,” “longitudinal,” “lateral,” and the like, as used herein, shall mean in relation to the bottom or the furthest extent of the surrounding wellbore, even if the wellbore or portions thereof may be offset or horizontal. Correspondingly, the orientations transverse, axial, lateral, longitudinal, radial, etc., shall mean orientations relative to the orientation of the wellbore or tool. Additionally, the illustrated embodiments are illustrated such that the orientation is such that the right side is hole below compared to the left side.

[0083] The term “coupled” is defined as connected, either directly or indirectly, through intervening components, and is not necessarily limited to physical connections. The connection may be such that the objects are permanently connected or releasably connected. Petition 870220047449, dated 05 / 31 / 2022, pages 66 / 80 27 / 29 connected. The term “outside” refers to a region that is beyond the outermost limits of a physical object. The term “inside” indicates that at least a portion of a region is partially contained within a boundary formed by the object. The term “substantially” is defined as being essentially in conformity with the dimension, shape, or other particular word that substantially modifies, such that the component need not be exact. For example, substantially cylindrical means that the object resembles a cylinder, but may have one or more deviations from a true cylinder.

[0084] The term “radially” means substantially in a direction along a radius of the object, or having a directional component in a direction along a radius of the object, even if the object is not exactly circular or cylindrical. The term “axially” means substantially along a direction from the axis of the object. If not specified, the term axially is such that it refers to the longest axis of the object.

[0085] Although a variety of information has been used to explain aspects within the scope of the appended claims, no limitation of the claims should be implied based on particular features or arrangements, since a common learner would be able to derive a wide variety of implementations. Furthermore, and although some matter may have been described in language specific to structural features and / or steps of the method, it should be understood that the matter defined in the appended claims is not necessarily limited to these described features or acts. Such functionality may be distributed differently or implemented in components other than those identified in this document. The features and steps described are disclosed as possible components of systems and methods within the scope of the appended claims.

[0086] Furthermore, claim language citing “at least one of” a set indicates that one member of the set or several members of the set satisfy the claim. For example, claim language citing “at least one of A and B” means A, B or A and B.

[0087] Disclosure statements include:

[0088] Statement 1. A method comprising: utilizing a distributed fiber optic detection cable connected to a cementing tool disposed in a wellbore, the distributed fiber optic detection cable being configured to obtain strain detection data. Petition 870220047449, dated 05 / 31 / 2022, pp. 67 / 80 28 / 29 distributed along the well; receive strain detection data distributed along the well from the distributed fiber optic detection cable; determine distributed measurement pressure data based on the distributed strain detection data received from the distributed fiber optic detection cable; and determine a strain value based on the distributed measurement pressure data and the distributed strain detection data.

[0089] Statement 2. The system of statement 1, in which the distributed fiber optic detection cable is configured to transmit optical signals through the well and transmit backscattered optical signals.

[0090] Statement 3. The system of statements 1-2, in which the received distributed strain detection data includes Brillouin measurements based on backscattered optical signals.

[0091] Statement 4. The system of statements 1-3, in which optical signals are modulated with respect to frequency, amplitude or phase.

[0092] Statement 5. The system of statements 1-4, further comprising measuring a change in the frequency of the backscattered optical signals.

[0093] Statement 6. The system of statements 1-5, in which the received distributed strain detection data includes Rayleigh measurements based on backscattered optical signals.

[0094] Statement 7. The system in statements 1-6, where the strain value is at least one of pressure and temperature.

[0095] Declaration 8. The system of declarations 1-7, further comprising presenting at least one pressure and temperature reading in a user interface.

[0096] Statement 9. The system of statements 1-8, in which pressure and temperature are measured simultaneously using the distributed fiber optic detection cable.

[0097] Statement 10. The system of statements 1-9, wherein the cementing tool is a cementing top cap or a cementing top cap dart.

[0098] Statement 11. A system comprises: a cementing tool configured to be placed in a wellbore; a distributed detection system Petition 870220047449, dated 05 / 31 / 2022, pages 68 / 80 29 / 29 comprising: a distributed fiber optic detection cable configured to connect to the cementing tool; and an interrogator positionable on a wellbore surface configured to: receive strain detection data distributed along the wellbore from the distributed fiber optic detection cable; and determine distributed measurement pressure data from the distributed strain detection data; and a processor in communication with the distributed detection system and configured to determine a strain value based on the distributed measurement pressure data and the distributed strain detection data.

[0099] Statement 12. The system of statements 11, in which the distributed fiber optic detection cable is configured to transmit optical signals through the well and transmit backscattered optical signals.

[0100] Statement 13. The system of statements 11-12, where the received distributed strain detection data includes Brillouin measurements based on backscattered optical signals.

[0101] Statement 14. The system of statements 11-13, where the received distributed strain detection data includes Rayleigh measurements based on backscattered optical signals.

[0102] Statement 15. The method of statement 11-14, in which optical signals are modulated with respect to frequency, amplitude or phase.

[0103] Statement 16. The method of statement 11-15, wherein the distributed detection system is at least one of a distributed temperature detection system and a distributed strain detection system.

[0104] Statement 17. The method of statements 11-16, where the strain value is at least one of pressure and temperature.

[0105] Statement 18. The method of statements 11-17, in which at least one of pressure and temperature is presented in a user interface.

[0106] Statement 19. The method of statements 11-18, in which pressure and temperature are measured simultaneously using the distributed fiber optic detection cable.

[0107] Statement 20. The method of statements 11-19, wherein the cementing tool is a cementing top cap or a cementing top cap dart. Petition 870220047449, dated 05 / 31 / 2022, pp. 69 / 80

Claims

1 / 3 CLAIMS 1. Method (400), characterized in that it comprises: (402) utilizing a distributed fiber optic detection cable connected to a cementing tool disposed in a wellbore (102), the distributed fiber optic detection cable being configured to obtain strain detection data distributed along the wellbore (102); (404) receiving the strain detection data distributed along the wellbore (102) from the distributed fiber optic detection cable; (406) determining distributed measurement pressure data based on the distributed strain detection data received from the distributed fiber optic detection cable (122); and (408) determining a strain value based on the distributed measurement pressure data and the distributed strain detection data.

2. Method (400), according to claim 1, characterized in that the distributed fiber optic detection cable (122) is configured to transmit optical signals through the well (102) and transmit backscattered optical signals.

3. Method (400), according to claim 2, characterized in that the received distributed strain detection data includes Brillouin measurements based on backscattered optical signals.

4. Method (400), according to claim 2, characterized in that the optical signals are modulated with respect to frequency, amplitude or phase.

5. Method (400), according to claim 4, characterized in that it further comprises measuring a change in the frequency of the backscattered optical signals.

6. Method (400), according to claim 2, characterized in that the received distributed strain detection data includes Rayleigh measurements based on backscattered optical signals.

7. Method (400), according to claim 1, characterized in that the strain value is at least one of pressure and temperature.

8. Method (400), according to claim 7, characterized in that it further comprises displaying at least one pressure and temperature display in a user interface. Petition 870260052178, dated 29 / 05 / 2026, p. 10 / 15 2 / 3 9. Method (400), according to claim 7, characterized in that pressure and temperature are measured simultaneously using the distributed fiber optic detection cable (122).

10. Method (400), according to claim 1, characterized in that the cementing tool is a cementing top plug or a cementing top plug dart.

11. System (2, 100), characterized in that it comprises: a cementing tool configured to be disposed in a wellbore (102); a distributed detection system comprising: a distributed fiber optic detection cable configured to connect to the cementing tool; and an interrogator positionable on a wellbore surface (102) configured to: receive strain detection data distributed along the wellbore (102) from the distributed fiber optic detection cable; and determine distributed measurement pressure data from the distributed strain detection data; and a processor (510) in communication with the distributed detection system (2, 100) and configured to determine a strain value based on the distributed measurement pressure data and the distributed strain detection data.

12. System (2, 100) according to claim 11, characterized in that the distributed fiber optic detection cable is configured to transmit optical signals through the well (102) and transmit backscattered optical signals.

13. System (2, 100), according to claim 12, characterized in that the received distributed strain detection data includes Brillouin measurements based on backscattered optical signals.

14. System (2, 100), according to claim 12, characterized in that the received distributed strain detection data includes Rayleigh measurements based on backscattered optical signals.

15. System (2, 100), according to claim 12, characterized in that the optical signals are modulated with respect to frequency, amplitude or phase. Petition 870260052178, dated 05 / 29 / 2026, p. 11 / 15 3 / 3 16. System (2, 100), according to claim 11, characterized in that the distributed detection system is at least one of a distributed temperature detection system and a distributed strain detection system.

17. System (2, 100), according to claim 11, characterized in that the strain value is at least one of pressure and temperature.

18. System (2, 100), according to claim 17, characterized in that at least one of the pressure and temperature readings is presented in a user interface.

19. System (2, 100), according to claim 17, characterized in that pressure and temperature are measured simultaneously using the distributed fiber optic detection cable.

20. System (2, 100), according to claim 11, characterized in that the cementing tool is a cementing top plug or a cementing top plug dart. Petition 870260052178, dated 05 / 29 / 2026, page 12 / 15

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