The present disclosure generally relates to a system and method for modifying a plug container to permit a fiber pass-through to allow data to be communicated from a pressurized environment into a non-pressurized environment. The present disclosure further relates to a system and method for deploying a fiber surrounded by a fiber sheath during pumping operations.
In the oil and gas industry, it can be required to measure characteristics and/or compositions of substances located at remote subterranean locations and convey the result to the earth's surface for processing and analysis. For instance, it may be required to measure chemical and/or physical properties of substances located in subterranean hydrocarbon-bearing formations and convey the results of the measurement over long distances to the earth's surface. The measurements may be carried out using electrical devices; however, there is a limited amount of electrical power available to operate such devices and transmit the measurements over long distances to the surface using electrical signals with a high signal-to-noise ratio (SNR).
During completion of the wellbore, the annular space between the wellbore wall and a casing string (or casing) can be filled with cement. The process is referred to as “cementing” the wellbore. A lower plug can be inserted into the casing string after which cement can be pumped into the casing string. An upper plug can be inserted into the wellbore after a desired amount of cement has been injected. The upper plug, the cement, and the lower plug can be forced downhole by injecting displacement fluid into the casing string. Variations in the pressure of the displacement fluid can be used to determine the location of the upper plug, the cement, and the lower plug. These variations in pressure can be small and may not always be detected or may be incorrectly interpreted. Accurate information relating to the position of the upper plug, and thereby the cement below it, can prevent damage to the well or other errors in the cementing process. For example, variations in the pressure of the displacement fluid can occur when the lower plug gets trapped at an undesired location in the casing string, this can be incorrectly interpreted to mean the lower plug has reached its destination at a float collar at the bottom of the casing string.
In order to describe the manner in which the advantages and features of the disclosure can be obtained, a more particular description of the principles briefly described above will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings. Understanding that these drawings depict only exemplary embodiments of the disclosure and are not therefore to be considered to be limiting of its scope, the principles herein are described and explained with additional specificity and detail through the use of the accompanying drawings in which:
It will be appreciated that for simplicity and clarity of illustration, where appropriate, reference numerals have been repeated among the different figures to indicate corresponding or analogous elements. In addition, numerous specific details are set forth in order to provide a thorough understanding of the examples described herein. However, it will be understood by those of ordinary skill in the art that the examples described herein can be practiced without these specific details. In other instances, methods, procedures, and components have not been described in detail so as not to obscure the related relevant feature being described. Also, the description is not to be considered as limiting the scope of the embodiments described herein. The drawings are not necessarily to scale and the proportions of certain parts may be exaggerated to better illustrate details and features of the present disclosure.
Knowing the location of the upper cement plug can increase the integrity of the well cementing process. As such, there is a need in the art to be able to deploy a top plug having a fiber coupled therewith into an oil and gas well that can be released under pressure, such as during pumping operations. A fiber deployed in this manner must also be able to continuously transmit data from within the wellbore to surface equipment. A major problem in deploying a fiber during pumping operations is that pressure differentials across the plug container (such as a cement head) need to be maintained. For example, the fiber connection at the surface is at atmospheric pressure conditions, whereas the fiber connection on the downhole side of the plug container is subject to wellbore conditions (such as increased pressures and temperatures). No plug container currently exists which is capable of releasing a fiber or facilitate communications via a top plug during pumping operations. The modification to a plug container described herein provides a means to allow for continuous data communication between surface and downhole, including an adequate seal such that no pressure bleeds through the fiber connection device.
The present disclosure further relates to systems and methods for modifying a plug container to allow for a pass through by means of a bladder or pack-off to allow a fiber to transfer data from a pressurized condition to atmospheric conditions. For example, the unique modification of an existing plug container allows the fiber to pass through the cap of the plug container to allow deployment of the fiber during high-pressure pumping operations within the wellbore. In at least one example the pass through can include a threaded attachment. In the alternative, the pass through can include an opening to allow for a push-through coupling.
In addition, the proposed methodology as further described herein to convey a fiber via a top plug may require the top plug to be longer in length than a conventional top plug. Therefore, a secondary modification to the plug container can be made to accommodate a longer top plug which may contain a fiber spool therein. Modifications disclosed herein can extend to include drill-pipe heads as well as casing heads to allow use in liner, sub-sea and casing applications.
Furthermore, to obtain viable information from downhole the fiber must be protected from fluid displacement within the casing that may stress the fiber in an axial direction. Stress caused by fluid movement about the fiber can damage the fiber, causing the fiber to fail. As such, the present disclosure further relates to methods and systems for providing a sheath that can be placed over a bare fiber to reduce the forces placed on the fiber within the wellbore. In at least one instance, the sheathing can be affixed to the plug container such that the stress imparted from fluid movement is applied to the sheath rather than the fiber. As such, the fiber is not subjected to any stress from the displacement of the plug during the deployment of the fiber.
The modified plug container and fiber sheath described above can be used in a wellbore during a pumping operation.
An example technique and system for placing a cement composition into a wellbore drilled through a subterranean earth formation will now be described with reference to
Modifications, additions, or omissions may be made to
Turning now to
With continued reference to
Referring back to
As it is introduced, the cement composition 14 may displace other fluids 36, such as drilling fluids and/or spacer fluids, which may be present in the interior of the casing 30 and/or the wellbore annulus 32. At least a portion of the displaced fluids 36 may exit the wellbore annulus 32 via a flow line 38 and be deposited, for example, in one or more retention pits 40 (e.g., a mud pit), as shown in
Modifications, additions, or omissions may be made to
In at least one instance, a top plug capable of deploying a fiber into the wellbore can be used in accordance with the present systems and methods. In such instances, the top plug can have differing lengths to account for the length of fiber stored therein.
The ability to be able to affix a fiber to a plug container for the purpose of tracking a cement plug as it is displaced into an oil and gas well would provide a competitive advantage. Specifically, real-time active tracking a plug as it is placed into an oil and gas well can allow a determination of the nature of the success of the cementing operation based at least in part on the information captured by the deployed fiber. As stated above, the ability to capture information can be dependent upon the survivability of the fiber during displacement. Methods and systems disclosed herein further provide for a sheath configured to protect a bare fiber cable from fluid displacement and flow that would otherwise damage the fiber.
In at least one instance, the fiber can be a fiber optic cable which can house one or several optical fibers. The optical fibers may be single mode fibers, multi-mode fibers, or a combination thereof. Fiber optic sensing systems connected to the optical fibers may include Distributed Temperature Sensing (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 single point sensing systems where the sensors are located at the end of the cable.
The fiber optic sensing systems may operate using various sensing principles including, but not limited to, amplitude based sensing systems like, e.g., DTS systems based on Raman scattering, phase sensing based systems like, e.g., DAS systems based on interferometric sensing using e.g., homodyne or heterodyne techniques where the system may sense phase or intensity changes due to constructive or destructive inferences, strain sensing systems like DSS using dynamic strain measurements based on interferometric sensors or static strain sensing measurements using e.g., Brillouin scattering, quasi-distributed sensors based on e.g., Fiber Bragg Gratings (FBGs) where a wavelength shift is detected or multiple FBGs are used from Fabry-Perot type interferometric sensors for phase or intensity based sensing, or single point fiber optic sensors based on Fabry-Perot or FBG or intensity based sensors.
In at least one instance, electrical sensors may also be present. Such electrical sensors may be pressure sensors based on quarts type sensors, strain gauge based sensors, or other commonly used sensing technologies. Pressure sensors, optical or electrical, may be housed in dedicated gauge mandrels or attached outside the casing in various configuration for downhole deployment or deployed conventionally at the surface wellhead or flow lines.
Various hybrid approaches were single point, quasi-distributed, or distributed fiber optic sensors are mixed with e.g., electrical sensors, are also anticipated. The fiber optic cable may then include optical fiber and electrical conductors.
Temperature measurements from e.g., a DTS system may be used to determine locations for fluid inflow in the treatment well as the fluids from the surface are likely to be cooler than formation temperatures. It is known in the industry to use DTS warm-back analyses to determine fluid volume placement, this is often done for water injection wells and the same technique can be used for fracturing fluid placement. Temperature measurements in observation wells can be used to determine fluid communication between the treatment well and observation well, or to determine fluid formation movement.
DAS data can be used to determine fluid allocation in real-time as acoustic noise is generated when fluid flows through the casing and in through perforations into the formation. Phase and intensity based interferometric sensing systems are sensitive to temperature and mechanical as well as acoustically induced vibrations. DAS data can be converted from time series date to frequency domain data using Fast Fourier Transformations (FFT) and other transforms like wavelet transforms may also be used to generate different representations of the data. Various frequency ranges can be used for different purposes and where e.g., low frequency signal changes may be attributed to formation strain changes or fluid movement and other frequency ranges may be indicative of fluid or gas movement. Various filtering techniques may be applied to generate indicators of events than may be of interest. Indicators may include formation movement due to growing natural fractures, formation stress changes during the fracturing operations and this effect may also be called stress shadowing, fluid seepage during the fracturing operation as formation movement may force fluid into and observation well and this may be detected, fluid flow from fractures, fluid and proppant flow from fracturing hits. Each indicator may have a characteristic signature in terms of frequency content and/or amplitude and/or time dependent behavior, and these indicators may be. These indicators may also be present at other data types and not limited to DAS data.
DAS systems can also be used to detect various seismic events where stress fields and/or growing fracture networks generate micro-seismic events or where perforation change events may be used to determine travel time between horizontal wells and this information can be used from stage to stage to determine changes in travel time as the formation is fractured and filled with fluid and proppant. The DAS systems may 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 determine production effectiveness.
DSS data can be generated using various approaches and static strain data can be used to determine absolute strain changes over time. Static strain data is often measured using Brillouin based systems or quasi-distributed strain data from FBG based systems. Static strain may also be used to determine propped fracture volume by looking at deviations in strain data from a measured strain baseline before fracturing a stage. It may also be possible to determine formation properties like permeability, poro-elastic responses and leak off rates based on the change of strain vs 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 like dynamic changes to fluid flow rates in the treatment well, addition of diverters or chemicals into the fracturing fluid or changes to proppant concentrations or types can then be used to mitigate detrimental effects.
Fiber Bragg Grating based systems may also be used for a number of different measurements. FBG's are partial reflectors that can be used as temperature and strain sensors, or can be used to make various interferometric sensors with very high sensitivity. FBG's 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. FBG's can be manufactured into an optical fiber at a specific wavelength, and other systems like DAS, DSS, or DTS systems and may operate at different wavelengths in the same fiber and measure different parameters simultaneously as the FBG based systems using Wavelength Division Multiplexing (WDM).
The fiber can be placed in the well to measure well characteristics and provide communication. As described above, the fiber can track a top plug as it moves throughout a wellbore and capture temperature and pressure information corresponding thereto. Data obtained by the fiber optic sensor can be transmitted to a control or processing facility (not shown) at the surface of the wellbore. The control or processing facility may include a computing device capable of carrying out the methods and techniques of the present disclosure, including collecting and analyzing data gathered by the fiber. In some instances, the computing device can be equipped to process the received information in substantially real-time. In other instances, the computing device can be equipped to store the received information for processing at some subsequent time. The computing system is described in greater detail with respect to
In at least one instance, the sheath 380 for protecting the fiber 370 can be contained within, and dispensed out of, the top plug 390 during displacement of the top plug 390 from the plug container 300. For example, the sheath 380 can be placed over the fiber 370 and then wound around a bobbin or reel placed within the top plug 390 such that the fiber 370 and sheath 380 can be unwound as the top plug 390 is deployed.
In at least one instance, the sheath 380 for protecting the fiber 370 can be disposable and designed for single use. In the alternative, the sheath 380 can be reusable and designed for repeated uses.
In at least one instance, the fiber 370 pass through of the cap 310 can be include a bladder or pack-off to allow the fiber to transmit data through a pressurized condition within the plug container 300 to an atmospheric condition outside the plug container 300. As described above, the pack-off can be similar to those used in typical wireline operations. For example, the pass through can include a hydraulic element which squeezes around the circumference of the fiber 370. In at least one instance, the hydraulic element can be pumped up with a hydraulic press. Once the cementing job and evaluation is completed, the hydraulic element can be relieved and the fiber 370 and sheath 380 can be removed from the plug container 300 and reloaded for another job. In the alternative, a connector can be present on the inside of the cap 310 (high pressure side) that has a high-pressure connection to where a cable can be attached on the outside of the cap 310 (low pressure side) in order to transfer the information.
In at least one instance, a method for using the above described system can include deploying a fiber within a protective sheath. The protective sheath having the fiber therein can then be spooled and placed inside a modified top plug, which allows the fiber and sheath to be unwound as the top plug moves throughout the wellbore.
The input/output device 540 may provide input/output operations for the system 500. In some instances, the input/output device 540 can include one or more network interface devices. In some instances, the input/output device can include driver devices configured to receive input data and send output data to other input/output devices including, but not limited to, keyboards, printers, and display devices 560. In some instances, mobile computing devices, mobile communication devices, and other devices can be used.
Numerous examples are provided herein to enhance understanding of the present disclosure. A specific set of statements are provided as follows.
Statement 1: A plug container comprising an elongated body having a first end, a second end, and a flow path therethrough; a cap coupled with the first end of the elongated body, the cap further comprising a pass-through for receiving a communication line; a threaded connector at the second end of the elongated body for coupling a casing; and a top plug sized to fit within the flow path of the elongated body and couplable with the communication line.
Statement 2: A plug container in accordance with Statement 1, wherein the top plug further comprises a cavity for storing a length of the communication line therein.
Statement 3: A plug container in accordance with Statement 1 or Statement 2, further comprising a reel stored within the cavity of the top plug and receiving the length of communication line.
Statement 4: A plug container in accordance with Statements 1-3, further comprising a protective sheath coupled with the top plug and the pass-through of the cap, the protective sheath enclosing the communication line therein.
Statement 5: A plug container in accordance with Statements 1-4, wherein the protective sheath is one or more of a plastic, a polymer, and a metal alloy.
Statement 6: A plug container in accordance with Statements 1-5, wherein the elongated body is sized to fit the top plug having the cavity therein.
Statement 7: A plug container in accordance with Statements 1-6, wherein the pass-through of the cap further comprises a bladder for maintaining a pressure within the elongated body.
Statement 8: A plug container in accordance with Statements 1-6, wherein the pass-through of the cap further comprises a pack-off for maintaining a pressure within the elongated body.
Statement 9: A plug container in accordance with Statements 1-8, wherein the communication line is a fiber optic cable to obtain and transmit data to a surface control facility.
Statement 10: A plug container in accordance with Statements 1-9, wherein the data includes one or more of a temperature, a pressure, and a top plug location.
Statement 11: A plug container in accordance with Statements 1-10, further comprising one or more pins removably communicable with the flow path of the elongated body, the one or more pins directing the movement of the top plug through the flow path.
Statement 12: A plug container in accordance with Statements 1-11, further comprising one or more valves coupled with the elongated body for providing a fluid flow into the flow path of the elongated body.
Statement 13: A system for evaluating a wellbore having a casing disposed therein, the system comprising a communication line for obtaining data within the wellbore, the communication line having a protective sheath surrounding a length thereof; a plug container coupled with and to facilitate repositioning of the communication line, the plug container comprising an elongated body having a first end, a second end, and a flow path therethrough, a cap coupled with the first end of the elongated body, the cap further comprising a pass-through for receiving the communication line, and a threaded connector at the second end of the elongated body for coupling the casing within the wellbore; a top plug sized to fit within the flow path of the plug container and couplable with the communication line and protective sheath; and a control facility communicatively coupled with the communication line, the control facility including one or more processors coupled with at least one non-transitory computer-readable storage medium storing instructions which, when executed by the one or more processors, cause the processors to releasing the top plug from the plug container and into the casing of the wellbore, receive, via the communication line, data relating to wellbore conditions, and evaluating the wellbore conditions.
Statement 14: A system in accordance with Statement 13, further comprising a cementing tool positionable at the surface of the wellbore for pumping a cement composition through the casing.
Statement 15: A system in accordance with Statement 13 or Statement 14, wherein the plug container further comprises one or more valves coupled with the elongated body for providing a fluid flow from the cementing tool into the flow path of the elongated body; and one or more pins removably communicable with the flow path of the elongated body, the one or more pins directing the movement of the top plug through the flow path of the plug container during a cementing process.
Statement 16: A system in accordance with Statements 13-15, wherein the evaluation of the wellbore conditions includes determining the effectiveness of the cementing process.
Statement 17: A system in accordance with Statements 13-16, wherein the wellbore conditions include one or more of a temperature, a pressure, and a top plug location.
Statement 18: A system in accordance with Statements 13-17, wherein the top plug further comprises a cavity for storing a length of the communication line therein; and a reel stored within the cavity for receiving and dispensing the length of communication line surrounded by the protective sheath.
Statement 19: A system in accordance with Statements 13-18, wherein the protective sheath is one or more of a plastic, a polymer, and a metal alloy.
Statement 20: A system in accordance with Statements 13-19, wherein the pass-through of the cap further comprises a bladder for maintaining a pressure within the elongated body of the plug container.
Statement 21: A system in accordance with Statements 13-19, wherein the pass-through of the cap further comprises a pack-off for maintaining a pressure within the elongated body of the plug container.
Statement 22: A system in accordance with Statements 13-21, wherein the communication line is a fiber optic cable to obtain and transmit data to a surface control facility.
Statement 23: A method for evaluating a wellbore, the method comprising inserting a length of a communication line into a protective sheath; coupling a first end of the protective sheath with a top plug and a second end of the protective sheath with a cap of a plug container, the plug container comprising an elongated body having a first end, a second end, and a flow path therethrough, the flow path sized to fit the top plug therein, the cap coupled with the first end of the elongated body and further comprising a pass-through for receiving the remaining communication line, and a threaded coupling at the second end of the elongated body; deploying the top plug within the plug container via the fiber into a wellbore casing coupled with the threaded coupling of the plug container during a cementing process; and obtaining data, via the communication line, corresponding to one or more wellbore conditions, the one or more wellbore conditions including at least a temperature, a pressure, and a top plug location.
Statement 24: A method in accordance with Statement 23, further comprising transmitting the data corresponding to one or more wellbore conditions to a control facility communicatively coupled with the communication line, and evaluating, via one or more processors of the control facility, the wellbore conditions to determine an effectiveness of the cementing process.
Statement 25: A method in accordance with Statement 23 or Statement 24, wherein the top plug further comprises a cavity for storing a length of the communication line therein.
Statement 26: A method in accordance with Statements 23-25, further comprising a reel stored within the cavity of the top plug and receiving the length of communication line.
Statement 27: A method in accordance with Statements 23-26, wherein the protective sheath is one or more of a plastic, a polymer, and a metal alloy.
Statement 28: A method in accordance with Statements 23-27, wherein the elongated body is sized to fit the top plug having the cavity therein.
Statement 29: A method in accordance with Statements 23-28, wherein the pass-through of the cap further comprises a bladder for maintaining a pressure within the elongated body.
Statement 30: A method in accordance with Statements 23-28, wherein the pass-through of the cap further comprises a pack-off for maintaining a pressure within the elongated body.
Statement 31: A method in accordance with Statements 23-30, further comprising positioning a cementing tool at the surface of the wellbore for pumping a cement composition through the casing.
Statement 32: A method in accordance with Statements 23-31, wherein the communication line is a fiber optic cable to obtain and transmit data to a surface control facility.
Statement 33: A method in accordance with Statements 23-32, further comprising providing a fluid flow from the cementing tool into the flow path of the elongated body via one or more valves coupled with the elongated body of the plug container; and directing the movement of the top plug through the flow path of the plug container via one or more pins removably communicable with the flow path of the elongated body.
The embodiments shown and described above are only examples. Even though numerous characteristics and advantages of the present technology have been set forth in the foregoing description, together with details of the structure and function of the present disclosure, the disclosure is illustrative only, and changes may be made in the detail, especially in matters of shape, size and arrangement of the parts within the principles of the present disclosure to the full extent indicated by the broad general meaning of the terms used in the attached claims. It will therefore be appreciated that the embodiments described above may be modified within the scope of the appended claims.
This application claims priority to U.S. Provisional Patent Application 62/968,928, which was filed in the U.S. Patent and Trademark Office on Jan. 31, 2020, and U.S. Provisional Patent Application 62/968,962, which was filed in the U.S. Patent and Trademark Office on Jan. 31, 2020, which are incorporated herein by reference in their entirely for all purposes.
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