• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
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    • 专利摘要:
    METHOD FOR OBTAINING INFORMATION ABOUT SUBSUPERFACE FORMATION FROM ACOUSTIC SIGNALS CONTAINING INFORMATION ABOUT SUBSUPERFACE FORMATION A method for obtaining information about the subsurface formation of acoustic signals that contains information about subsurface formation, including: providing an optical fiber having a proximal end and a remote end, with the proximal end being coupled to a light source and a proximal photodetector, wherein said fiber optic cable includes randomly spaced impurities and selectively placed bragg networks and where the fiber optic cable it is acoustically coupled to the formation of subsurface in order to allow acoustic signals to affect the physical state of at least one network: transmitting at least one pulse of light within the cable; receiving in the photodetector a first light signal indicative of the physical state of at least a first section of the cable, and emitting at least one item of information to a display.
    公开号:BR112012008690B1
    申请号:R112012008690-1
    申请日:2010-10-15
    公开日:2020-10-13
    发明作者:Dennis Edward Dria；Jeremiah Glen Pearce；Frederick Henry Kreisler Rambow
    申请人:Shell Internationale Research Maatschappij B.V；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    [0001] The invention relates to a method of increasing the spatial resolution of an optical detection system including Bragg networks over fiber in parts of the optical fiber. BACKGROUND OF THE INVENTION
    [0002] Seismic surveys are used to study subsurface formations in many contexts, including monitoring subsurface hydrocarbon reservoirs and tracking fluids, eg oil, gas, or water, as they flow through the subsurface terrain. . One type of sandy monitoring that is gaining in importance is the ability to track CO2 that has been injected as part of carbon capture and sequestration (CCS) projects. Also of interest in the context of subsurface monitoring are the various fluids that are used for enhanced oil recovery (EOR), hydrocarbon saturation, fractionation operations, and the like.
    [0003] Conventional seismic monitoring is typically multi-dimensional, with three dimensions in relation to the spatial characteristics of land formation. Typically two dimensions are horizontal length dimensions, while the third concerns the depth in the formation of the earth, which can be represented by a length coordinate, or by a coordinate such as the two-way travel time of a seismic wave to from the surface to a certain depth and back. In addition, seismic data is also often acquired by at least two points in time, providing a fourth dimension. This allows changes in the seismic properties of the subsurface to be studied as a function of time. Changes in seismic properties over time may be due to, for example, spatial and temporal variation in fluid saturation, pressure and temperature.
    [0004] Seismic monitoring techniques investigate subsurface formations by the generation of seismic waves on the earth and measurements over time the waves need to travel between one or more seismic sources and one or more seismic receivers. The travel time of a seismic wave is dependent on the length of the path crossed, and the speed of the wave along the path.
    [0005] A typical system includes several sound receivers implanted across the region of interest. It is not uncommon to use hundreds or even thousands of acoustic sensors to collect data across a desired area, as illustrated in Figure 1. In instances where the sensors are placed in a borehole, few sensors are used, and the information available is correspondingly limited.
    [0006] Acoustic signals containing seismic data recorded by seismic sensors are known as traces. The recorded traces are analyzed to derive an indication of the geology in the subsurface or other information. In order to maximize repeatability, the sensors are ideally left in place for the duration of the monitoring period.
    [0007] Conventional seismic monitoring of oil or gas fields has several disadvantages. First, it is relatively expensive to acquire, deploy and maintain a large number of geophones or hydrophones that are necessary in order to provide the desired level of resolution for periods of time that are typically involved, which can be in the order of years.
    [0008] Second, the resolution of conventional systems is limited by the number and location of the acoustic receivers. Some acoustic systems exist in which acoustic events are detected by monitoring changes in backscattered light on a fiber optic cable that is physically affected by the acoustic events. These systems are referred to as Distributed Acoustic Detection (DAS) systems and operate using principles similar to Optical Time Domain Reflectometry (OTDR). In OTDR, a fiber optic cable is probed with a laser pulse from an interrogation unit. Glass defects spread the pulse (Rayleigh scattering) as it propagates along the fiber and scattered photons are received in a photodetector. The data is used to map the reflectivity of the fiber along its length. DAS uses a similar technique, in which external acoustic disturbances modulate the backscattered light from certain sections of the fiber. By recording these traces at high data rates (~ 5 kHz), DAS transforms the fiber into a large number of distributed microphones or sensors.
    [0009] These systems avoid the need for separate acoustic sensors such as geophones or hydrophones, but depend on impurities in the optical cable to cause scattering. Because sensitivity depends on impurities, the scattered signal may be weak or non-existent in parts of the cable where it is desired to detect. Current DAS systems provide spatial resolution in the order of 1-10m. This failure in several situations, including inflow monitoring applications, where relevant events can be well located (<lm). The source of this limitation is due to the compromise between pulse length (or spatial resolution) and sensitivity measurement. A larger laser pulse can provide a larger number of scattered photons, but a larger section of the fiber.
    [00010] For this reason, it is desirable to provide a sandy seismic monitoring system that is inexpensive to acquire, deploy, and maintain, and that can provide high resolution with respect to the region of interest. The region of interest may include a part of the subsurface that is important for hydrocarbon production or because it is undergoing a change in acoustic properties as compared to other regions or because it requires different seismic sampling spacing (spatial or temporal) in contrast to other regions . SUMMARY OF THE INVENTION
    [00011] The present invention provides a sandy seismic monitoring system that is inexpensive to acquire, deploy, and maintain, and that can provide high resolution with respect to the region of interest.
    [00012] In some embodiments, the invention provides a method for obtaining information about subsurface formation from acoustic signals that contains information about subsurface information, comprising a) providing at least one fiber optic cable implanted within the acoustic range of subsurface formation, the fiber optic cable having a proximal end and a remote end, the proximal end being coupled to a light source and a proximal photodetector, wherein the fiber optic cable includes randomly spaced impurities and a plurality of Bragg networks over fiber placed selectively and where the fiber optic cable is acoustically coupled to the formation of subsurface in order to allow the acoustic signals to affect the physical state of at least one network, b) transmit at least one pulse of c) receive a first light signal on the photodetector indicating the physical state of at least a first section of the cable, d) to further process the first and second items of information in order to produce derived information; and e) send at least one of the first item of information and derived information to a exhibitor.
    [00013] Step a) may include selecting the location of the Bragg networks using pre-existing information on the formation of the subsurface.
    [00014] The method cable may include a proximal section that is free of Bragg mesh and a distal section that includes the plurality of Bragg mesh and the proximal section is 10 times larger than the distal section.
    [00015] At least a portion of the cable that includes at least one of the Bragg nets can be attached to equipment located in a borehole and the cable can be used to detect at least two selected aspects of the group consisting of acoustic events within or outside the borehole, fluid flow in the borehole, deformation or corrosion of the pipe or casing in the borehole, pressure changes in the borehole, and / or changes in the deformed state of the formation around the borehole. poll. The at least two aspects are preferably detected without modification or intervention of the cable.
    [00016] A part of the cable is wrapped around a tubular component in a well or can include loops or curves that increase the cable's sensitivity to deformation. BRIEF DESCRIPTION OF THE DRAWINGS
    [00017] For a more detailed understanding of the invention, reference is made to the drawings that accompany here: Figure 1 is a schematic illustration of a prior art system; Figure 2 is a schematic illustration of a system built according to the first embodiment of the invention; Figures 3-5 are schematic illustrations of a system according to the invention in use for a period of time; and Figure 6 is a schematic illustration of a system constructed in accordance with the second embodiment of the invention.
    [00018] As used here, the term "surface" refers to the surface of the land and in marine applications to the seabed. "On the surface" items are acoustically coupled to the ground by direct or indirect physical contact with the surface, such as being laid on the surface or being placed in shallow trenches, as opposed to being placed under the surface, such as in a borehole.
    [00019] As used here, the term "area" refers to an amount of surface that is detected by a cable or cable section, with the boundaries of the area being established by an imaginary parallel line to the surface and designed to include that cable or cable section.
    [00020] As used here the term "cable" generally refers to optical fiber, optical fiber cable, or any other device that is capable of transmitting optical signals, with or without sheaths or other characteristics. DETAILED DESCRIPTION OF A PREFERRED EMBODIMENT
    [00021] Referring initially to Figure 1, a set of conventional acoustic sensors 12 can be implanted as shown. The number of sensors available to cover the desired area is typically limited by cost; once the number of available sensors is established, the sensors are implanted. For shore applications, sensors must be deployed manually, such as using a GPS system to place each sensor in a desired location, or they can be installed in the bottom of shallow boreholes drilled for this purpose. For offshore applications, the sensors, referred to as Ocean Bottom Seismometers (OBS) must be deployed by remotely operated vehicle (ROV) and placed on the seabed in desired locations, or they can be deployed in wired configurations with spacings from intersensors fixed through the Ocean Bottom Cables (OBC) seated on the seabed.
    [00022] Regardless of the mode or manner of deployment, it is often desired to acquire data having more resolution than is available. Without additional sensors, it is impossible to collect such data.
    [00023] The present invention provides the ability to collect data in a manner that allows for higher resolution. Additionally, the present system has the ability to be both adaptable and / or programmable. According to preferred embodiments of the present invention, a fiber optic cable is connected to a light transmitting source arranged at a proximal end of the cable. The light source transmits at least one pulse of light at the end of the fiber optic cable. The cable can have a double end, for example, it can be folded in the middle so that both ends of the cable are at the source, or it can be a single end, with one end at the source and the other end at a point that is remote from the source. The cable length can vary from a few meters to several kilometers, or even hundreds of kilometers. In both cases, measurement can be based solely on backscattered light, if there is a means of receiving light only at the source end of the cable, or a means of receiving light can be provided at the second end of the cable, so that the light intensity at the second end of the fiber optic cable can also be measured.
    [00024] In some modalities, a single long cable is implanted over the area to be monitored. In other modalities, a cable can be implanted in a well. A modality of a DAS 20 system is shown in Figure 2 and includes a single fiber optic cable deployed in a spiral. Cable 22 is preferably a single-mode fiber optic wire connected to a signal processing center 26. Signal processing center 26 includes a light source (not shown) arranged to introduce an optical signal at an input end of the cable 22 and a proximal photodetector (not shown) arranged to detect radiation that has been reflected or backscattered within the cable 22 towards the input end and generate an output signal in response to the detected radiation.
    [00025] Fiber with FBGs tend to have large losses and thus more spread than fiber without FGBs. Thus, sections of fiber containing FBGs produce signals of greater amplitude and do not require such a long laser pulse, thus improving spatial resolution. This is particularly applicable in well applications, where acoustic surveillance is only required in a small part of the well that requires a long reach cable (> 10,000 feet (3048 m)).
    [00026] In one embodiment of the invention, Fiber Bragg Railings (FBGs) are included in the parts of the fiber that are located close to sections of the environment that are of particular interest. For example, if the fiber has been implanted in a well, FBGs will preferably be included in parts of the fiber that pass through the production zones. The locations of the production zones can be determined using pre-existing data, such as profiling of drill cable or the like.
    [00027] As illustrated, if applied to the surface, cable 22 can be arranged so that it extends radially out of the signal processing center 26 in a spiral, but it will be understood that one or more cables can be arranged in any other suitable arrangement , such as a multi-spiral configuration shown in Figure 6, a grid, or any other suitable configuration.
    [00028] In other modalities cable 22 can be implanted in one or more boreholes. In some embodiments, the cable can be supplied together around the bore equipment below. By way of example only, fiber optic cable can be lowered into an existing well and will be free in the well hole, where it is typically surrounded by liquid. In other embodiments, the fiber optic cable can be attached to the jacket or production or injection tubing at intervals, or affixed along its length using a suitable adhesive or the like. In yet other embodiments, the fiber optic cable can be positioned outside the sheath so that it is acoustically coupled to the formation by cementing the circular crown.
    [00029] In still other modalities, fiber optic cable can be included in several bore tools below and well completion components, such as sand retaining screens, drilled or slotted casings, other sand control components and telescopic joints , or included in other tools typically used for well intervention such as coiled tubing, hollow composite or solid tubes, braided cables, communication cables for transport profiling tools or flat line cables, or included in such or similar devices that are transported into the existing well specifically for the purpose of obtaining the necessary acoustic information. In this case, the degree of acoustic coupling requirement may depend on the nature and completion status of each well and the nature of the source and acoustic signals.
    [00030] In still other modalities, cable 22 or at least the part of cable 22 that contains any of the Bragg sensors on fiber is placed in a well in a way that allows it to deform on the scale that can measure large displacements and deformations in the well . Preferably, amplitude of reflection and change in frequency response predictably in response to such inputs. In these modalities, cable 22, or a portion thereof, is configured in one or more “snake” sensors, “loop” sensors, and / or “helical” sensors with folded Bragg networks over fiber essentially positioned in the folds of these sensors, everything is preferably included in a protective sheath, in a way where response changes caused by displacement forces correspond with and are indicative of the desired information, such as seismic events. In the case of “snake” or “S” sensors, further compression of said structure of acoustic events results in an increase in said bandwidth that can be predicted and calibrated for data provided. In the case of “loop” sensors, an increase in compression will result in a decrease in fold and a decrease in bandwidth.
    [00031] In still other modalities, cable 22 or at least part of cable 22 that contains some of the Bragg sensors on fiber can be incorporated into a structure to be monitored, the sensors then provide seismic monitoring. Once the system is in place at a well, the system can either be continuously monitored or periodically monitored without entering the well or changing the well in any way. Fiber gauges are highly reliable and should easily last the life of a well. Examples of such systems are discussed in U.S. Patent No. 6,854,327.
    [00032] Cable 22, or at least the part of cable 22 that contains Bragg nets, is preferably acoustically coupled to a subsurface formation, so that the acoustic signals traveling from the region of interest can affect the physical state of the cable. By altering the physical state of the cable, acoustic signals create a localized or semi-localized change in the cable's spreading properties, which in turn can be detected by a photodetector. Using techniques that are known in the art, the optical signals received from the cable can be used to extract information about the position and magnitude of the incoming acoustic signal (s).
    [00033] In some embodiments, the light source is a stable laser in a phase of long coherence length and is used to transmit encoded light from the direct sequence propagation spectrum below the fiber. Acoustic vibrations or other interruptions cause small changes to the fiber, which in turn produces changes in the backscattered light signal. The return of the light signal thus contains both information about the acoustic vibration and information indicating the location of where along the sound fiber it impacts the fiber. The location of the acoustic signal along the fiber can be determined using the spreading spectrum encoding, which only encodes the flight time along the length of the fiber.
    [00034] Using optical time domain reflectometry (OTDR) technology, it is impossible to determine an amount of backscattered light reaching from any point along the fiber optic cable 22. Although the duration of the light pulse determines a lower limit on resolution space, the resulting signal can be used to extract information over any longer interval. This can be accomplished by dividing the backscattered light signal into a series of points in time. The data within each point are added together to give information about the average deformation in the fiber length between the end points of the point. These points can be made arbitrarily wide for long sample sections of the fiber. The points can be sized equally and continuously propagated over the total length of the fiber with the end of one point becoming the beginning of the next, but if desired, the size and position of each point, in addition to the spacing between consecutive points, can be adapted to yield the optimal desired spatial sampling resolution. This programmatically distributed detector allows maximum resolution sampling over intervals of greatest interest without over-sampling regions of minor interest.
    [00035] Thus, by selecting the received backscatter signal, cable 22 can be treated as a plurality of discrete acoustic “sensors”, with each sensor corresponding to a cable section. Time selection can be controlled to produce sections / sensors that are as long or as short as desired. Referring again to Figure 2, for example, a portion of cable 22 can detect at high resolution, using relatively short sections of cable having Li lengths, as shown in 24, while another portion of cable 22 can detect at a lower resolution, using relatively long cable sections having lengths L2, as shown in 25. In some embodiments, high resolution section length Li is preferably 0.5 to 10 m and low resolution section length L2 is preferably 10 to 100 + M.
    [00036] An example of a suitable technology is a system called Blue Rose. This system explores the physical phenomenon of Rayleigh optical dispersion, which occurs naturally in optical fibers traditionally used for optical time domain reflectometry (OTDR) techniques. Blue Rose detects backscattered light and uses the signal to provide information about acoustic events caused by activities near the cable. The sensor is a single, single-mode fiber optic wire with an elastomeric coating that is buried in the floor to a depth of approximately nine inches (22.86 centimeters). Alternatively, coherent OTDR (C-OTDR) processes can be used to obtain similar acoustic information from an optical system, as disclosed in US Order No. 20090114386.
    [00037] Still further, the present invention can be used in conjunction with a multiplexing wavelength division and / or multiplexing frequency division. Since Bragg networks over fiber can be formed in order to be more reflective at a particular wavelength, it may be desirable in some cases to provide networks differently tuned along the length of the fiber, in order to increase sensitivity in the desired sections .
    [00038] Because the present invention combines the adaptability of distributed acoustic detection with the precision and predictability of Bragg networks over fiber, it provides a single system that can be used for seismic survey or monitoring, well monitoring, tubular monitoring and monitoring training. A single cable 22, properly placed in a well, can detect external or interior acoustic events, inflow, deformation or corrosion of pipes or linings, pressure changes, and / or changes in the deformation state of the formation. In addition, the system can switch from one measurement type to another without modification or intervention.
    [00039] Fiber optic cable 22 can be deployed on or near the Earth's surface or below the surface, such as in a borehole. Using the approach described above, cable 22 can be used to detect acoustic signals (vibrations) from naturally occurring events, induced subsurface events, or seismic sources active on or below the surface. An example of a subsurface acoustic event is an inflow of fluid, where fluid from the formation, whether gas or liquid, seeps into the borehole. Depending on the well and well location, such inflows may be desirable or undesirable. Regardless, a system can detect and locate such inflows that would be advantageous. In addition, data collected from the present invention can be processed to simulate data from "virtual sources" as are known in the art, or the system can be used to record signals from virtual sources.
    [00040] Still referring to Figure 2, cable 22 can have an optional second photodetector 28 disposed at its remote end. Remote photodetector 28 preferably communicates with the signal processing center 26 via wireless signal or other suitable means. If present, remote photodetector 28 will receive light that has been transmitted along the length of the cable. The level or intensity of light received by remote photodetector 28 can be compared to a base level, where the base level is preferably the intensity that is received on remote photodetector 28 when the system is in normal operation with no disturbance to the fiber cable optics 22.
    [00041] In one embodiment, signal processing center 26 continuously samples the amount of backscattered light in each section along the fiber optic cable 22 and compares the backscattered light intensity with a previous sample to determine whether a sufficient change in intensity of scattered light occurred and if so, at what point (s). This approach is useful for detecting fiber disturbances, but it can generate volumes of data that are not practical to handle, particularly if the sections are relatively short.
    [00042] Thus, in another modality, detection and location of backscattered light can be triggered by detecting a change in light intensity on the remote photodetector 28. Because this allows for the storage of less volumes of data, this approach can be advantageous in cases where there are limitations on the amount of data that can be collected or processed. Many acoustic events are expected to last long enough to be detected by the system's post-activation. If it is desirable to ensure that no anticipated event data is lost, a continuous update memory buffer can be used to store the scattered light from the fiber optic cable 22, only transferring data sets to a permanent medium when triggered by a change in light on the photodetector 28.
    [00043] In other modalities, the system can be programmed to increase the sampling resolution when triggered by detecting a change in light in the photodetector 28.
    [00044] In still other embodiments, one or more sections of cable can be used as monitoring devices, so that the system modifies its resolution in one or more areas or stores data from a temporary memory storage in response to a change in signal from one or more of the designated monitoring device sections. Thus, for example, if a very large detection system is used, it may be desirable to designate a subset of possible detection sections as monitoring sections and to change the detection density in the vicinity of a particular detection section in response to a change on the signal received from that section.
    [00045] The flexibility of each acoustic detection cable can be influenced to build a sandy seismic recording network with programmable spatial distribution that provides optimal resolution when adapted to the focus on the regions of interest. Regions of interest can relate to the presence of fluid, pressure, or temperature fronts such as those that develop over time due to production, CCS, EOR, or other processes. In an exemplary embodiment, programmatically distributed detection with finely spaced sensors can be employed in areas where reservoir processes vary rapidly in a side detector, while coarse distributions can be employed elsewhere. The sensor interrogation program and effective sensor distribution pattern can be adapted to track areas of interest as production evolves over time.
    [00046] In still other modalities, it should be desirable to record with two different resolutions when the subsurface includes both shallow and deep objectives.
    [00047] In still embodiments of the invention they illuminate the data storage and processing load by detecting only desired portions of the fiber and decaying the parts that are detected. An example of such a system is shown in Figures 3-5, in which a system 40 is dynamically monitored to track the movement of a fluid front 30 as it traverses the system from left to right as drawn, as indicated by the arrows. Sequential figures 3-5, spectrum indicators 44 represent sections of cable 42 that are selected for detection. Once the location of the fluid front 30 has been stabilized, detection can be limited to sections 44 that rest in the vicinity of the front. As the front moves through the detection area, the selection of sections to detect also changes, with some sections being interrogated ceasing and interrogation of some sections being started, in order to maintain a high resolution image of the front without sampling unnecessary data . In this mode, both the amount (area) of coverage and the detection location can be varied.
    [00048] In other embodiments, the invention can provide variable time resolution of a detection network that is distributed in space. In this case, spatial resolution is maximized anywhere in the field, but an acceptable time resolution, for example 1 week, is selected and data with high spatial resolution is multiplexed over time to provide information about the entire network in discrete time steps. Both spatial and temporal resolutions are preferably independently variable and programmable.
    [00049] The adaptive detection network can be arranged in conventional 2D or 3D recording geometries, such as at or near the surface seismic acquisition, near the seabed for marine acquisition of the ocean floor, and in the water for marine acquisition . In some environments, it may be sufficient to place the optical cable on the Earth's surface, while in other environments it may be preferable to bury the cable in a shallow trench in order to intensify its acoustic coupling to the Earth. The adaptive detection network can also be installed in horizontal or vertical boreholes, diverted to seismic hole acquisition below. These boreholes can be dedicated observation wells or production-related wells. Network installation is envisioned to be on a permanent basis, to maximize coupling to training and to reduce data acquisition costs.
    [00050] The present adaptive monitoring system can record acoustic signals generated by seismic energy sources that can be placed on the surface, in water, or in boreholes, or can be passive in nature (micro-seismic). The monitoring systems that can result from such combinations of sources and adaptive detection networks include all known geometries, such as 2D or 3D surface seismic, 2D or 3D sea or ocean floor seismic, 2D or 3D VSP seismic, transverse well, micro-seismic monitoring in boreholes or on hydraulic fracturing surfaces or EOR processes, etc. Likewise, the present invention can be used to monitor all modes of propagation including reflection and refraction waves (shear and compressional), surface waves, Loca waves and other guided modes. When fiber optic cables are implanted down the hole in horizontal wells, such configurations allow the use of virtual source seismic techniques, which are useful for monitoring the reservoir over complex overload.
    [00051] To maximize the benefits of the adaptability of the detection network, the present system preferably has high fiber resolution along (eg ~ 1m of fine spacing and up to 10m for coarse spacing). For sandy monitoring applications, optical fibers are preferably arranged in patterns such as the detection net covers the subsurface maximally, for example meshed patterns or spiral in shallow trenches. Spiral drill holes can also be used.
    [00052] The adaptability of the present system is also advantageous when the detection environment is limited or changes. For example, in systems where it is not possible to place current sensors in all desired locations, because of physical or similar obstacles, the present system can be programmed to adapt the absence of sensor by providing increased sampling density at points adjacent to the obstacle . Data from these points can be processed to give information about the obstructed area.
    [00053] In other embodiments, a system as described in U.S. Application No. 2008277568 can be used. This system uses pulsed pairs of light signals that have different frequencies and are separated in time. If used, such a system allows signal processing to be performed more easily and with a higher signal-to-noise ratio which is the case if radiation from a single frequency backscattered from different positions along the length of the optical fiber is used to generate a signal in a photodetector by interferometry.
    [00054] While the present invention has been described in terms of preferred embodiments, it will be understood that various modifications to it can be made without departing from the scope of the invention, as set out in the claims that follow. By way of example only, a person skilled in the art will recognize that the number and configuration of cables and sensors, the sample rate and frequencies of light used, and the nature of the cable, coupling devices, light sources and photodetectors can all be modified.
    权利要求:
    Claims (5)
    [0001]
    1. A method for obtaining information on a subsurface formation from acoustic signals containing information on the subsurface formation, comprising: a) providing at least one fiber optic cable (22) implanted on the surface and within the acoustic range of the formation subsurface, the fiber optic cable (22) having a proximal end and a remote end, the proximal end being coupled to a light source and a proximal photodetector, where the fiber optic cable (22) includes impurities randomly spaced and a plurality of selectively placed Bragg over fiber networks, in which the optical fiber cable (22) is acoustically coupled to the formation of a subsurface in order to allow the acoustic signals to affect the physical state of at least one network, in which at least at least a portion of the cable that includes at least one of the Bragg networks over fiber is attached to the equipment located in a borehole; b) transmit at least one pulse of light on the fiber optic cable (22); c) receiving on the photodetector a first light signal selected from the group consisting of acoustic events inside or outside the borehole, fluid flow inside the borehole, deformation or corrosion of the pipe or liner in the borehole, pressure changes in the borehole, and / or changes in the deformed state of the formation around the borehole in at least one first section of the fiber optic cable (22); d) optionally, repeat steps a) - c) in order to collect a second light signal indicating the physical state of a second section of the fiber optic cable (22) and still process the first and second light signals in order to produce derived information; and e) emit at least one of a light signal and the derived information to a exhibitor; characterized by the fact that the location of the Bragg networks in step a) is selected using pre-existing information on subsurface formation, and in which the cable is used to detect at least two different aspects of the group defined in step c).
    [0002]
    2. Method according to claim 1, characterized by the fact that the cable includes a proximal section that is free of Bragg nets and a distal section that includes the plurality of Bragg nets and the proximal section is 10 times larger than the section distant.
    [0003]
    3. Method according to claim 1, characterized by the fact that at least two aspects are detected without modification or intervention of the cable.
    [0004]
    4. Method according to claim 1, characterized by the fact that at least a part of the cable is wound around the tubular in a well.
    [0005]
    5. Method according to claim 1, characterized by the fact that at least part of the cable includes turns or curves that increase the sensitivity of the cable to deformation.
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    同族专利:
    公开号 | 公开日
    US20100200744A1|2010-08-12|
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    GB2485960A|2012-05-30|
    AU2010306670B2|2013-11-28|
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    GB2485960B|2014-08-20|
    MY181583A|2020-12-29|
    AU2010306670A1|2012-05-10|
    BR112012008690A2|2017-06-13|
    CA2777069A1|2011-04-21|
    WO2011047255A3|2011-07-21|
    WO2011047255A2|2011-04-21|
    CA2777069C|2018-04-03|
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    法律状态:
    2019-01-08| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-07-16| B06T| Formal requirements before examination [chapter 6.20 patent gazette]|
    2019-11-05| B07A| Application suspended after technical examination (opinion) [chapter 7.1 patent gazette]|
    2020-05-19| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-10-13| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 15/10/2010, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US12/580,130|2009-10-15|
    US12/580,130|US8315486B2|2009-02-09|2009-10-15|Distributed acoustic sensing with fiber Bragg gratings|
    PCT/US2010/052835|WO2011047255A2|2009-10-15|2010-10-15|Distributed acoustic sensing with fiber bragg gratings|
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