FIBER OPTIC INTERROGATION SYSTEM
20220334279 · 2022-10-20
Inventors
Cpc classification
G01N29/2418
PHYSICS
G02B6/4215
PHYSICS
E21B47/135
FIXED CONSTRUCTIONS
International classification
G01V1/22
PHYSICS
E21B47/135
FIXED CONSTRUCTIONS
Abstract
A sensing optical fiber includes multiple waveguides or cores to allow sensing of multiple measurands using a single fiber. The fiber can be a dual clad fiber having a single mode core and a multi-mode core disposed radially or circumferentially about the single mode core. A dual clad fiber coupler couples source light from a DAS interrogator and a DTS interrogator into the dual clad fiber in use.
Claims
1. A fiber optic sensing system for use in a wellbore, the system comprising: a multicore optical fiber; DAS instrumentation comprising an interrogator; DTS instrumentation comprising an interrogator; and a coupler, wavelength division multiplexer, or optical switch disposed between the multicore optical fiber and the DAS and DTS instrumentation.
2. The system of claim 1, further comprising a wavelength filtering device placed between the coupler, wavelength division multiplexer, or optical switch and the DAS instrumentation.
3. The system of claim 2, wherein the wavelength filtering device is a thin film filter.
4. The system of claim 1, wherein the multicore optical fiber comprises a multi-mode core waveguide concentrically or radially surrounding a single mode core waveguide.
5. The system of claim 1, wherein the system has a double ended configuration and a first end of the multicore optical fiber is coupled to the coupler, wavelength division multiplexer, or optical switch and a second end of the optical fiber is coupled to the DTS instrumentation.
6. The system of claim 1, further comprising a second coupler, wavelength division multiplexer, or optical switch disposed between the multicore optical fiber and the DTS instrumentation, wherein a first end of the multicore optical fiber is coupled to the coupler, wavelength division multiplexer, or optical switch and a second end of the optical fiber is coupled to the second coupler, wavelength division multiplexer, or optical switch.
7. The system of claim 1 comprising a plurality of multicore optical fibers and a plurality of couplers, wavelength division multiplexers, or optical switches, each of the plurality of couplers, wavelength division multiplexers, or optical switches associated with one of the plurality of multicore optical fibers.
8. The system of claim 7, further comprising a switch disposed between the DAS instrumentation and the plurality of couplers, wavelength division multiplexers, or optical switches, the switch configured to multiplex the DAS instrumentation.
9. A method of deploying a multicore optical fiber in a wellbore, the method comprising: deploying a control line in the wellbore, the control line comprising a metal tube; and pumping the multicore optical fiber into the control line.
10. The method of claim 9, wherein the multicore optical fiber comprises a multi-mode core waveguide concentrically or radially surrounding a single mode core waveguide.
11. The method of claim 9, wherein pumping the multicore optical fiber comprises using water, Toluene, Xylene, and/or IPA as a carrier medium.
12. The method of claim 9, wherein the wellbore is completed with a multi-stage completion having an upper completion and a lower completion, and pumping the multicore optical fiber allows the multicore optical fiber to reach the lower completion.
13. The method of claim 12, wherein deploying the control line comprises using a CLWM to couple a first portion of the control line in the upper completion with a second portion of the control line in the lower completion.
14. The method of claim 13, wherein pumping the multicore optical fiber comprises deploying continuous optical fiber through the first and second portions of the control line to reach the lower completion.
15. The method of claim 9, wherein deploying the control line comprises coupling the control line to an outside of production tubing deployed in the wellbore.
16. The method of claim 9, wherein deploying the control line comprises disposing the control line outside of a casing of the wellbore and cementing the control line in place.
17. The method of claim 9, wherein deploying the control line comprises disposing the control line within coiled tubing.
Description
BRIEF DESCRIPTION OF THE FIGURES
[0009] Certain embodiments, features, aspects, and advantages of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein.
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DETAILED DESCRIPTION
[0032] In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure. It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the disclosure. These are, of course, merely examples and are not intended to be limiting. However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments are possible. This description is not to be taken in a limiting sense, but rather made merely for the purpose of describing general principles of the implementations. The scope of the described implementations should be ascertained with reference to the issued claims.
[0033] As used herein, the terms “connect”, “connection”, “connected”, “in connection with”, and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element”. Further, the terms “couple”, “coupling”, “coupled”, “coupled together”, and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements”. As used herein, the terms “up” and “down”; “upper” and “lower”; “top” and “bottom”; and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements. Commonly, these terms relate to a reference point at the surface from which drilling operations are initiated as being the top point and the total depth being the lowest point, wherein the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.
[0034] The present disclosure generally relates to systems and methods for performing distributed optical fiber measurements, for example, on a dual-clad or multicore optical fiber. Such systems and methods can be used in the oil and gas industry, for example, for reservoir, well, and asset monitoring. Fiber optic sensing systems can be used for distributed temperature, strain, and/or vibration (acoustic) monitoring. Such systems can include interrogators and optical fibers acting as distributed sensors. In use, light is pulsed into the optical fiber. As light passes along the fiber, tiny amounts of the light interact with the structure of the fiber and are scattered back towards the acquisition instrument.
[0035] Three primary types of scattering occur.
[0036] Fiber optic sensing system interrogators leverage various scattering mechanisms within the optical fiber material. Different types of optical fibers can be particularly well suited for different measurands. For example, multi-mode fiber can be well-suited for temperature measurements, and single-mode fiber can be well-suited for strain and vibration measurements.
[0037] For use in oil and gas wells, such sensing optical fibers can be deployed in pre-installed control lines (e.g., metal tubing) via a pumping method. The fiber is pumped, typically with water (e.g., sea water in some cases), Toluene, Xylene, and/or IPA as a carrier medium, into the pre-installed control lines or metal tubing. The control lines can traverse a length of the well and loop back to the surface in a U configuration to provide an output for pumping fluids and enable double-ended fiber interrogation. Alternatively, the control lines can traverse the length of the well and terminate downhole, such that only one end of the tubing is accessible at the surface. The lines and fibers are typically terminated at the surface, often with pressure barrier componentry. The fibers can be spliced to surface cabling that connects to the interrogators.
[0038] Fiber can be pumped or installed in single stage and two-stage completions. In a single stage completion, the control line is continuous along the length of the well. The control line 20 can be deployed in various configurations, for example, connected to the outside of production 30 tubing as shown in
[0039] The pumping process can become complex if multiple fibers are required for monitoring multiple different measurands. For example, traditionally, to acquire simultaneous DAS, DSS, and DTS measurements, at least three optical fiber sensors would have to be deployed along the wellbore. The fibers would need to be pumped sequentially, and there is a high risk of the fibers becoming entangled, which could block the tubing. If tangling or blockage occurs, the fibers must be broken into small pieces and pumped out, then the process must be repeated with new fibers, which is costly and time consuming.
[0040] Therefore, some systems and methods according to the present disclosure include a multicore fiber 50. The multicore fiber 50 allows for simultaneous sensing, for example DAS, DSS, and/or DTS, in multistage completions. The multicore fiber 50 is a single fiber structure that includes more than one waveguide or core. The multicore fiber 50 can include multiple waveguides of the same or different types, such as multiple single mode cores 52 as shown in
[0041] In some configurations, the multicore fiber 50 includes a single-mode 52 waveguide or core and a multi-mode 54 waveguide or core. In some configurations, the waveguides are arranged co-axially or concentrically, and the multicore fiber can be considered a dual clad fiber (DCF) 10, for example as shown in
[0042] Some DAS (distributed acoustic sensing) systems, for example, the hDVS system available from Schlumberger, can operate on single-mode (SM) or multi-mode (MM) fibers. The hDVS system operates by measuring the phase of Rayleigh scattered light on a single ended (SE) optical fiber. As the system measures phase rather than amplitude, it is not critical to know the loss along the fiber. Some DTS (distributed temperature sensing) systems, for example, the DTS Ultra system available from Schlumberger, can operate on multi-mode fibers. The system operates on the basis of Raman scattering, measuring the differential between Stokes and anti-Stokes bands, with the anti-Stokes being more sensitive to temperature. Measuring the multi-mode fiber in each direction can help account for differential losses not due to temperature (e.g., bend losses, hydrogen darkening). Therefore, DTS systems can be used in single-ended and double ended configurations.
[0043] Detection technologies differ between DAS and DTS systems due to the excitation wavelengths of each system's lasers. More specifically, DTS operates at 1064 nm, while DAS operates at 1550 nm. DTS instrumentation uses a silicon based photodetector, which can detect 1064 nm while being insensitive to 1550 nm produced by DAS, as graphically shown in
[0044] Therefore, DTS light must be rejected before reaching the DAS instrumentation to prevent interference on the DAS measurements. This can be accomplished in two ways using spatial and wavelength division multiplexing. The dual clad fiber is a waveguide that can keep light channels spatially separate. The dual clad fiber can therefore be used to realize both DAS and DTS measurements. It is desirable to keep as much DAS light in the single mode part or core of the dual clad fiber as possible and as much DTS light in the inner clad region or multimode part or core of the dual clad fiber as possible.
[0045] Wavelength multiplexing can be achieved using a WDM (wavelength division multiplexer) 101.
[0046] Spatial multiplexing can be achieved using a dual clad fiber coupler 100. In some configurations, the coupler 100 can be used as an alternative approach to the WDM 101 shown in
[0047] As an alternative approach to the dual clad fiber coupler 100, an optical switch can be employed for time and spatial multiplexing. A custom switch, for example, using a technology such as MEMS, can be used in a 2×1 configuration. In such a configuration, Port 1 is dual clad fiber or single mode fiber, configured to be connected to the DAS. Port 2 is multi-mode fiber, configured to be connected to the DTS. The common is dual clad fiber, configured to be connected to the dual clad fiber to be deployed for measurement. This approach would require non-simultaneous measurement, and interrogation time would be divided between DAS and DTS. However, the process could be automated and allow the user to specify acquisition times depending on the application.
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[0049] The DTS and DAS source light traverse the dual clad sensing fiber 10 simultaneously. Both the DTS and DAS signals are subject to Rayleigh and Raman scattering. Light scattered backward is captured by the dual clad fiber and routed back to the interrogators 110, 120 via the coupler 100. A small quantity of DTS light may be scattered into the single mode core of the dual clad fiber 10 or coupled into the single mode core along the length of the fiber 10. This DTS light in the single mode core is rejected by the filter before reaching the DAS system.
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[0051] The dual clad fiber interrogation system of
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[0053] The existing multichannel functionality of the DTS interrogator 110 can be used in an application in which multiple sensing fibers 10 are to be used and interrogated. The DAS interrogator 120 can be expanded or multiplexed with a 1×n switch 150, for example as shown in
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[0055] Language of degree used herein, such as the terms “approximately,” “about,” “generally,” and “substantially” as used herein represent a value, amount, or characteristic close to the stated value, amount, or characteristic that still performs a desired function or achieves a desired result. For example, the terms “approximately,” “about,” “generally,” and “substantially” may refer to an amount that is within less than 10% of, within less than 5% of, within less than 1% of, within less than 0.1% of, and/or within less than 0.01% of the stated amount. As another example, in certain embodiments, the terms “generally parallel” and “substantially parallel” or “generally perpendicular” and “substantially perpendicular” refer to a value, amount, or characteristic that departs from exactly parallel or perpendicular, respectively, by less than or equal to 15 degrees, 10 degrees, 5 degrees, 3 degrees, 1 degree, or 0.1 degree.
[0056] Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims. It is also contemplated that various combinations or sub-combinations of the specific features and aspects of the embodiments described may be made and still fall within the scope of the disclosure. It should be understood that various features and aspects of the disclosed embodiments can be combined with, or substituted for, one another in order to form varying modes of the embodiments of the disclosure. Thus, it is intended that the scope of the disclosure herein should not be limited by the particular embodiments described above.