[0001 ] This application claims priority to U.S. provisional application serial number 62/367,523, filed July 27, 2016, which is incorporated by reference herein in its entirety.

BACKGROUND

[0002] Hydrocarbon fluids such as oil and natural gas are obtained from a subterranean geologic formation, referred to as a reservoir, by drilling a well that penetrates the hydrocarbon-bearing formation. Once a wellbore is drilled, various forms of well completion components may be installed in order to control and enhance the efficiency of producing the various fluids from the reservoir. Information from the wells can prove valuable, but reliably obtaining useful information from the well is difficult.

[0003] One manner in which information can be obtained from a well is to use a distributed fiber optic sensing system, such as a distributed temperature sensing system or a distributed vibration or acoustic sensing system. Fiber optic sensors employ the fact that environmental effects, such as pressure, strain, vibration, and temperature, can alter the amplitude, phase, frequency, spectral content, or polarization of light propagated through an optical fiber. Advantages of fiber optic sensors include their light weight, small size, passive nature, energy efficiency, and ruggedness. In addition, fiber optic sensors have the potential for very high sensitivity, and wide bandwidth. Yet further, certain classes of sensors can be distributed along the length of an optical fiber so that an appropriate interrogation system can be employed to monitor selected environmental parameters at multiple locations at the same time. For instance, when deployed in a hydrocarbon well, a fiber optic sensor can provide indications of characteristics of production fluids, such as fluid composition, density, viscosity, flow rate, etc. Various drilling, production and remedial operations can then be performed based on the information derived from the monitored parameters. BRIEF DESCRIPTION OF THE DRAWINGS

[0004] Certain embodiments of the invention are described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying drawings illustrate only the various implementations described herein and are not meant to limit the scope of various technologies described herein. The drawings show and describe various embodiments of the current invention.

[0005] Fig. 1 is a cross-sectional schematic view of a sensing system for obtaining simultaneous distributed measurements of different parameters from an optical sensing fiber deployed in a wellbore, according to an embodiment.

[0006] Fig 2. is a schematic illustration of a sensing system, according to an embodiment.

[0007] Fig. 3 is a schematic illustration of a sensing system, according to another embodiment.

[0008] Fig. 4 is a schematic illustration of an adapter for use in sensing system, according to an embodiment.

[0009] Fig. 5 is a graph of an idealized wavelength filter response of an adapter, according to an embodiment.

[0010] Fig. 6 is a flow diagram of an example technique for obtaining simultaneous distributed measurements of different parameters from an optical sensing fiber, according to an embodiment.

[001 1 ] Fig. 7 is a schematic illustration of a sensing system that includes discrete sensors, according to an embodiment.

SUMMARY

[0012] Certain embodiments of the present disclosure are directed to a distributed measurement system that includes a sensing fiber deployed along a desired measurement path. The system also includes first and second measuring instruments to generate probe signals to launch into the sensing fiber and to acquire measurement data from backscattered light generated in response to the probe signals. An adapter is coupled to the first and second measuring instruments and to an end of the sensing fiber. The adapter combines the probe signals for simultaneous launch into the fiber, separates the backscattered light generated in response to the combined probe signals and provides a first separated portion to the first measuring instrument and a second separated portion to the second measuring instrument.

[0013] Embodiments disclosed herein also are directed to a method for making simultaneous distributed measurements along an optical sensing fiber deployed along a desired measurement path. A distributed measurement of a first parameter of interest is acquired simultaneously with acquiring a distributed measurements of a second parameter of interest that is different than the first parameter.

[0014] Embodiments disclosed herein further are directed to a distributed measurement system for used in a wellbore. The system includes a sensing fiber deployed in the wellbore and an adapter to combine two or more probe signals to launch simultaneously into the fiber and to separate the backscattered light generated in response into a first backscatter portion and a second backscatter portion. A data acquisition system acquires measurement data from the first and second backscatter portions, where first data corresponds to a first parameter of interest and second data corresponds to a second parameter of interest that is different than the first parameter.

DETAILED DESCRIPTION

[0016] In the following description, numerous details are set forth to provide an understanding of the present invention. However, it will be understood by those skilled in the art that the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.

[0017] In the specification and appended claims: 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", "upwardly" and downwardly", "upstream" and "downstream"; "above" and "below"; and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the invention.

[0018] Embodiments of the present disclosure are directed to systems and techniques for using optical fibers to detect various environmental parameters of interest along the fiber. The optical fiber(s) can be deployed in an oilfield well or in any other suitable environment, such as for electrical cable monitoring, pipeline leak monitoring, fire detection, intrusion detection, etc. In oilfield well applications, as an example, characteristics of fluid flow in a well are of particular interest, including fluid density, viscosity, flow rate and composition (e.g., fractional composition of gas/water/oil). In general, one way to detect fluid flow is to monitor the ambient vibration or acoustic noise associated with the flow in a region of interest. This vibration or acoustic noise can be logged as a function of location and, thus, provide valuable information that can be used to control and/or enhance production, to perform remedial measures, and/or to assess well integrity (e.g., casing leaks, etc.). A fiber optic monitoring system, such as a system that employs an optical fiber that is configured to provide a distributed response to acoustic events, can be used to monitor the ambient flow noise in the region of interest. Temperature measurements also provide valuable information, and a fiber optic monitoring system that employs an optical fiber can be used to monitor the environmental conditions in the region of interest.

[0019] In general, fiber optic monitoring systems, particularly distributed fiber-optic monitoring systems, employ an optical source (e.g., a laser) to generate pulses of optical energy to launch into an optical fiber that is deployed in a region of interest (e.g., in a wellbore). As the launched pulses travel along the length of the optical fiber, small imperfections in the fiber reflect a portion of the pulses, generating backscatter. When the fiber is subjected to events in the region of interest (such as vibration or acoustic signals propagating through the region of interest, strain on the fiber, temperature changes, etc.), the distances between the imperfections change. Consequently, the backscattered light also changes. By monitoring the changes in the backscatter light generated by the fiber (e.g., spontaneous Raman scattering, stimulated Brillouin scattering, or Rayleigh scattering) in response to interrogating probe signals launched into the fiber from an interrogation system, it is possible to determine characteristics of the event(s) (e.g., temperature, strain, vibration) experienced by the fiber. The measured event(s) can then be used to derive information about the region of interest.

[0020] One type of fiber optic monitoring system is referred to as a Distributed Vibration Sensing (DVS or hDVS) system or, alternatively, a Distributed Acoustic Sensing (DAS) system. For convenience, DVS, hDVS and DAS systems are generally referred to herein as a DVS system. DVS systems have been used to efficiently gather data in applications such a pipeline security monitoring and vertical seismic profiling. DVS systems also have been deployed to monitor fluid flow in subterranean wellbores. Another type of fiber optic monitoring system is referred to as a Distributed Temperature Sensing (DTS) system. DTS systems have been used to derive a temperature profile in a wellbore and in other applications where temperature changes can provide information about a region of interest, such as to detect fluid flow, pipeline leaks, overheating conditions, stress, etc. Multiple types of distributed sensing systems and techniques are known and any of these types of known systems and techniques, as well as systems and techniques yet to be developed, can be used to obtain the distributed measurements described herein.

[0021 ] While DVS and DTS systems have been used in many types of applications, a single fiber generally is used for each different type of measurement. Consequently, multiple fibers must be installed in order to obtain simultaneous measurements of different types of parameters, increasing the cost of new installations and reducing compatibility with existing fiber deployment systems, such as a slickline or wireline unit or cable that may not contain the required number of fibers. Accordingly, embodiments of the present disclosure are directed to a device that allows different distributed measurements to be made simultaneously using a single fiber.

[0022] Turning now to Fig. 1 , a cross-sectional, schematic representation of a well 100 that penetrates a subterranean formation 102 is shown. The well 100 is formed by drilling a borehole 104 through the surface 106 so that it penetrates the subterranean formation 102. A casing 108 can then be lowered and set in place. In Fig. 1 , a cable containing a distributed fiber optic sensor 1 10 is deployed in the well 100 to measure parameters of interest. The sensor 1 10 extends through a wellhead 1 12 and terminates at a far end 1 14 at a depth in the borehole 104. Although a cased well structure is shown, it should be understood that embodiments of the invention are not limited to this illustrative example. Uncased, open hole, gravel packed, deviated, horizontal, multi-lateral, deep sea or terrestrial surface injection and/or production wells (among others) may incorporate the systems and techniques as described. Further, the fiber optic sensor 1 10 can be permanently installed in the well 100 or can be removably deployed in the well, such as for use during remedial operations.

[0023] The fiber optic sensor 1 10 generally is contained within a protective casing or a conduit (e.g., a control line). As shown in Fig. 1 , the fiber optic sensor 1 10 is coupled to a surface interrogation and acquisition system 1 16, which is arranged to acquire data from the optical fiber 1 10 using any suitable technique. To that end, the system 1 16 includes a first distributed measuring instrument 1 17 (e.g., a DTS instrument) and a second distributed measuring instrument 1 19 (e.g., a DVS instrument), both of which are configured to interrogate and acquire data from the optical fiber 1 10. Each of instruments 1 17 and 1 19 includes an optical source 1 18 (e.g., a coherent narrowband laser) to generate an optical probe signal (e.g., one or more pulses) to launch into the fiber 1 10, such as through a circulator. The instruments 1 17 and 1 19 also each includes an optical receiver/detector 120 (e.g., a photodetector) to detect backscattered light generated by the fiber 1 10 in response to the interrogating optical signal.

[0024] The arrangement shown in Fig. 1 also includes an adapter 122 that couples the instruments 1 17 and 1 19 to the sensing fiber 1 10 and allows for simultaneous measurements of different parameters of interest. Schematic illustrations of example deployments of the adapter 122 with instruments 1 17, 1 19 and sensing fiber 1 10 are shown in Figs. 2 and 3.

[0025] With reference to Fig. 2, a first example embodiment of a fiber optic sensing system 200 that includes the adapter 122 is schematically shown. In this embodiment, the sensing fiber 1 10 is connected to both instruments 1 17 and 1 19 through the adapter 122 and respective output fiber sections 125 and 127. In an embodiment, the sensing fiber 1 10 and the fiber section 125 can be multi-mode fibers, and the fiber section 127 can be a single-mode fiber. However, in other embodiments, any of the fiber 1 10 and the fiber sections 125 and 127 can be single-mode or multi-mode or any other type of optical fiber suitable for the application in which the sensing system 200 is deployed. In this embodiment, the sensing fiber 1 10 is configured for a single-ended measurement by the instruments 1 17, 1 19.

[0026] A second example embodiment of a fiber optic sensing system 300 that includes the adapter 122 is schematically illustrated in Fig. 3. Here, the sensing fiber 1 10 can be a multi-mode fiber that is connected to the instruments 1 17 and 1 19 through the adapter 122 and respective fiber sections 125 and 127. Also, as shown in Fig. 3, the sensing fiber 1 10 is arranged for double-ended measurements by instrument 1 17. That is, a first end of the fiber 1 10 is connected to the instrument 1 17 through the adapter 122 and fiber section 125, while the second end of the fiber 1 10 is connected directly to the instrument 1 17. In this way, the instrument 1 17 can launch probe signals into either end of the fiber 1 10 and detect backscattered light generated in response to the probes at either end of the fiber 1 10. And, again, it should be understood that any of the fibers 1 10, 125 and 127 can be any type of fiber, such as a single-mode or a multi-mode fiber.

[0027] It also should be understood that embodiments of the sensing systems described herein are not limited to sensing systems that include both a DTS system and a DVS system or to only two distributed sensing systems. Rather, the arrangements and techniques described herein also can be applied to sensing systems in which the adapter 122 enables two or more simultaneous distributed measurements from one sensing fibers. For example, the adapter 122 can be used to simultaneously measure two or more of distributed temperature, distributed strain, distributed vibration and distributed acoustic measurements.

[0028] It also should be understood that embodiments of the sensing systems described herein are not limited to sensing systems that include only one sensing fiber. Rather, the arrangements and techniques described herein also can be applied to sensing systems in which the adapter 122 enables two or more simultaneous distributed measurements from each of two or more sensing fibers. For example, the adapter 122 can be used to simultaneously measure temperature and vibration from a first fiber, and temperature and strain from a second fiber. In other words, embodiments of the present disclosure are directed to a device to enable simultaneous distributed measurements of two or more parameters from each of one or more fiber sensing fibers, where the number of sensing fibers in the system is less than the number of simultaneous measurements of different parameters of interest.

[0029] Turning now to Fig. 4, an embodiment of an adapter 122 is schematically illustrated. In this embodiment, the adapter 122 includes a wavelength division multiplexer (WDM) 130 to combine the different interrogation pulses launched into the sensing fiber 1 10 by multiple distributed measuring instruments, such as the instruments 1 17 and 1 19. The WDM 130 also splits the backscattered light generated by the fiber 1 10 in response to the combined interrogating pulses and directs the split backscatter to the appropriate measuring instrument 1 17 and 1 19. As an example, the WDM 130 can be configured to filter the received backscattered light so that the shorter wavelengths are passed to one of fiber sections 125, 127 and the longer wavelengths are passed to the other of fiber sections 125, 127 so the appropriate wavelengths are received by the appropriate measuring instrument 1 17, 1 19.

[0030] An example of an idealized filter response of the WDM 130 is illustrated in Fig. 5. As shown, the backscatter lighted input to WDM 130 from the sensing fiber 1 10 is split into two outputs, so that the high frequency wavelengths (represented by line 132) are provided to fiber section 125 and the low frequency wavelengths (represented by line 134) are provided to fiber section 127.

[0031 ] Returning to Fig. 4, the adapter 122 also includes elements 136 that are arranged to transform the interrogation pulses and backscatter so that they can be transmitted from one native fiber type to another. For example, in embodiments in which fiber sections 125 and 127 are a different native type than sensing fiber 1 10, elements 136 can transform the interrogation pulses transmitted on fiber section 124, for example, so that the pulses can be transmitted on sensing fiber 1 10. Likewise, the elements 136 can transform backscattered light received from sensing fiber 1 10 so that the backscatter can be transmitted on fiber section 125, as an example. By way of illustration, in an embodiment in which fiber section 125 is multimode fiber and section 127 is single mode fiber, elements 136 couple sections 125 and 127 to common single mode fiber to couple to the WDM 130.

[0032] In embodiments, use of the adapter 122 may introduce errors or otherwise affect the quality of the measurements obtained from the sensing fiber 1 10. For example, fiber couplings and the WDM 130 can add optical reflection and optical loss to the transmitted and received signals, thus reducing the backscatter signal and reducing the effective range of the instruments 1 17, 1 19. Consequently, the sensing system can also be configured to correct measurements obtained from the sensing fiber 1 10 to remove the effect of the adapter 122. As an example, a correction can be applied to the data acquired by instruments 1 17, 1 19 based on calibration information obtained from prior testing of the particular adapter 122 that is used to make the measurements. The instruments 1 17, 1 19 can be pre-configured with the appropriate correction information so that the correction is applied automatically as part of the acquisition of data from the backscattered light received by each of the instruments 1 17, 1 19.

[0033] In other embodiments, the correction can be implemented by using a double-ended measurement technique (as shown in Fig. 3) or by using multiple interrogation wavelengths. In such embodiments, both ends of the sensing fiber 1 10 are available to the surface instrument (e.g., instrument 1 17). Interrogation pulses are obtained from both ends of the fiber 1 10 and the fiber loss correction is derived from the double ended pulse configuration.

[0034] In embodiments, the adapter 122 itself can be configured to actively correct the measurements. For example, as shown in Fig. 4, the adapter 122 can include one or more reference coils 138 of optical fiber that are used to monitor reference signals amplitude and phase, under controlled conditions in reference coil(s) 138. Unwanted changes in the reference signal superimposed on the backscatter can then be removed from the backscatter signal.

[0035] In the embodiments described thus far, the measurements obtained from the sensing fiber 1 10 have been described as distributed measurements taken continuously along the length of the fiber 1 10. However, it should be understood that the present disclosure is not limited to such distributed measurements. For example, as shown in Fig. 7, the sensing system can be configured so that the instrument 1 17 acquires a distributed measurement while the instrument 1 19 acquires one or more point measurements obtained from discrete sensors 140 disposed along the length of the sensing fiber 1 10. The discrete sensors can be fiber Bragg gratings, as shown, or can be temperature or pressure gauges as further examples. Further, in some embodiments, one or more of the instruments 1 17 and 1 19 can be configured to obtain both distributed measurements and point measurements. For example, instruments 1 17, 1 19 can be configured to acquire backscatter generated by the natural imperfections in the glass of the sensing fiber 1 10, as well as backscatter generated by one or more fiber Bragg gratings formed in the fiber 1 10.

[0036] In addition to components to generate an interrogating pulse and detect the backscattered light generated by the fiber optic cable 1 10 in response, the measuring instruments 1 17, 1 19 can include a processing system 124 having one or more processing devices 126 and memory devices 128 to process the acquired data and to apply any correction to the acquired data to compensate for errors introduced by the adapter 122. In other embodiments, the data acquired by the instruments 1 17, 1 19 can be processed and corrected at a remote location.

[0037] Fig. 6 is a flow diagram of a technique for obtaining two or more simultaneous distributed measurements from one or more sensing fibers. At block 602, a sensing fiber (e.g., fiber 1 10) is deployed along a desired measurement path (e.g., wellbore 104). At block 604, a first measuring instrument (e.g., instrument 1 17) and a second measuring instrument (e.g., instrument 1 19) are coupled to the sensing fiber through an adapter (e.g., adapter 122). At block 606, the instruments 1 17 and 1 19 are operated to generate interrogating probes to launch into the fiber 1 10. At block 608, the adapter 122 combines the interrogating probes and directs the combined signal into the fiber 1 10. At block 610, the adapter 122 receives backscattered light generated by the fiber 1 10 in response to the combined interrogating probes, separates the backscattered light into portions (e.g., based on wavelength filtering), and provides the separated backscatter portions to the appropriate instruments 1 17 and 1 19. At block 612, the instruments 1 17 and 1 19 acquire measurement data from their respective received backscatter portions, where the data acquired from one portion corresponds to a different parameter of interest than the data acquired from another portion. At block 614, a correction is applied to the measurement data to correct for effects of the adapter 122.

[0038] The flow and sequence of blocks shown in Fig. 6 is an example. It should be understood that various of the blocks may be performed in other sequences. For example, the correction shown in block 614 can be applied by the adapter 122 before the separated backscatter is provided to the instruments 1 17, 1 19.

[0039] In some embodiments, the systems and techniques described herein can be employed in conjunction with an intelligent completion system disposed within a well that penetrates a hydrocarbon-bearing earth formation. Portions of the intelligent completion system may be disposed within cased portions of the well, while other portions of the system may be in the uncased, or open hole, portion of the well. The intelligent completion system can comprise one or more of various components or subsystems, which include without limitation: casing, tubing, control lines (electric, fiber optic, or hydraulic), packers (mechanical, sell or chemical), flow control valves, sensors, in flow control devices, hole liners, safety valves, plugs or inline valves, inductive couplers, electric wet connects, hydraulic wet connects, wireless telemetry hubs and modules, and downhole power generating systems. Portions of the systems that are disposed within the well can communicate with systems or sub-systems that are located at the surface. The surface systems or sub-systems in turn can communicate with other surface systems, such as systems that are at locations remote from the well. [0040] While the invention has been disclosed with respect to a limited number of embodiments, those skilled in the art, having the benefit of this disclosure, will appreciate numerous modifications and variations there from. It is intended that the appended claims cover such modifications and variations as fall within the true spirit and scope of the invention.