• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    SEISMIC TOOL, AND IN AN OPTICAL SEISMIC WELL, OPTICAL LIFTING SYSTEM METHOD OF INSTALLING OPTICAL SYSMIC TOOL IN A SEISMIC SURVEY OF THE WELL. A system, an apparatus and a method for installing optical fiber in a seismic optical well are disclosed. Modalities of the present disclosure may include methods of installing a distributed fiber optic sensor wound on a reel inside the well integrated with a ballast or weight for a seismic optical tool, in order to carry out the installation of a disposable light fiber optic cable against the well walls through gravity. The method can also include the unfolding of a distributed fiber optic sensor wound on a reel and c) use of the optical fiber as a distributed seismic receiver. After installing the distributed fiber optic sensor according to the methods of the present disclosure, surveys can be obtained and processed by various methods.
    公开号:BR112014016769B1
    申请号:R112014016769-9
    申请日:2013-01-04
    公开日:2020-11-10
    发明作者:Pierre Vigneaux；Arthur H. Hartog；Bernard Frignet
    申请人:Prad Research And Development Limited；
    IPC主号:
    专利说明:

    FUNDAMENTALS
    [0001] Seismic drilling surveys are among the bottom measurements used in the hydrocarbon industry. Originally, seismic drilling surveys were limited to time-based surface seismic images correlated to depth-based well profiles and depth-based reservoir models for the purpose of making drilling decisions. Modern seismic drilling applications, however, extend beyond simple depth-time correlations to generate a variety of useful information about reservoir extension, geometry and heterogeneity, as well as fluid content and pore pressure, mechanical properties of rock, improved oil recovery progress, elastic anisotropy parameters, induced rupture geometry and natural rupture orientation and intensity. Seismic drilling measurements have also extended beyond applications in the hydrocarbon industry to include applications in hydrology and in the underground carbon capture and storage industries.
    [0002] Regardless of the application, installation of seismic survey tools in wells may be restricted by cost and physical format considerations. For example, in the hydrocarbon production industry, drilling seismic surveying tools can have a diameter of two or more inches and thus may not physically fit into a well if both a drill string or pipe is in place (the unless detectors are placed on the drill string before drilling begins). As a result, performing a seismic drilling survey may involve pulling the drill string or production pipe (if either is in place), guiding an array of survey tools into the well, conducting the survey, pulling the tool matrix and then replace the drill string or tubing (if necessary). For this reason, a seismic survey can cost a lot, both in terms of probe time and, in some cases, lost production while the survey is being carried out.
    [0003] Drilling survey tools used as described above may include sensors and electronics at the bottom of the well. The harsh rock bottom environment increases the complexity and cost of sensors and electronics designed to withstand high temperatures and pressures for long periods of time. Consequently, seismic survey tools are generally not treated as disposable and may not be abandoned in the well after use or left inactive in a well for long periods (such as for time-lapse surveys) due to lost yields that can be obtained when installing survey tools in other locations. RESUME
    [0004] This summary is provided to present a selection of concepts that are better described below in the detailed description. This summary is not intended to identify the key or essential characteristics of the claimed subject matter nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.
    [0005] In one embodiment, an optical seismic tool is disclosed. The optical seismic tool may include a fiber optic cable spool coupled to a ballast of adjustable dimensions and a means of coupling to surface equipment comprising an optical source. The fiber optic cable spool unwinds through gravity after the installation of the ballast of adjustable dimensions in a well, the unwinding generating an acoustic coupling force between the fiber optic cable and the well.
    [0006] In one embodiment, an optical seismic survey system is disclosed. The optical seismic survey system may include a surface collection and control unit including a controller and an optical source. The optical seismic survey system may include a seismic source arranged on the surface at or in the well coupled to the surface control and collection unit that generates seismic signals when activated by the surface control and collection unit. The optical seismic survey system may include an optical seismic tool removably coupled to the surface collection and control unit. The optical seismic tool may include a fiber optic cable spool coupled to a ballast of adjustable dimensions and a means of coupling to surface equipment comprising an optical source. The fiber optic cable spool unwinds through gravity after the installation of the ballast of adjustable dimensions in a well, the unwinding generating an acoustic coupling force between the fiber optic cable and the well. The surface control and collection unit obtains, through a distributed fiber optic sensor, several optical measurements related to a characteristic of one of: 1) the well and 2) a formation through which the well is drilled, when the distributed sensor optical fiber is deformed by seismic signals.
    [0007] In one embodiment, a method is disclosed for installing an optical seismic tool in a well in seismic survey of the well. The method may include separately coupling an optical seismic tool on the surface to surface equipment including an optical source that launches optical pulses at the distributed fiber optic sensor. The method may include installing the optical seismic tool through gravity and a pressurized fluid force, thereby unwinding the fiber optic cable spool. The method may include the generation of an acoustic coupling force between the fiber optic cable and the well. The optical seismic tool comprises a fiber optic cable reel coupled to a ballast of adjustable dimensions and a means of coupling to the surface equipment. BRIEF DESCRIPTION OF THE FIGURES
    [0008] Modalities of a system, an apparatus and a method for the installation of optical fiber in a well in optical seismic survey are described with reference to the following figures. The same numbers are used throughout the figures to refer to similar characteristics and components.
    [0009] FIG. 1 is a schematic cross-sectional illustration of a transverse well seismic system including an optical seismic tool and a distributed fiber optic sensor, thereby installed in an uncoated well, according to one embodiment of the present disclosure.
    [0010] FIG. 2 is a schematic cross-sectional illustration of a transverse well seismic system including an optical seismic tool and a distributed fiber optic sensor, thereby installed in a pressurized fluid drill pipe, according to one embodiment of the present disclosure.
    [0011] FIG. 3 shows an illustration of a launching apparatus with an optical seismic tool in a launching position (for example, in a non-pressurized well), according to an embodiment of the present disclosure.
    [0012] FIG. 4 is an illustration of an optical seismic tool, according to one embodiment of the present disclosure.
    [0013] FIG. 5 is a flow chart of a method for installing an optical seismic tool in a well in a seismic well survey, according to one embodiment of the present disclosure. DETAILED DESCRIPTION
    [0014] In the following description, numerous details are established in order to provide an understanding of the present invention. However, it will be understood by those skilled in the art that the present disclosure can be practiced without these details and that numerous variations or modifications of the described modalities are possible.
    [0015] Disclosure relates to several methods for cost-effective installation of a disposable distributed fiber optic sensor in a well as part of a well seismic survey, the fiber optic sensor operable to obtain seismic signal measurements using coherent time domain reflectometry (Coherent Optical Time-Domain Reflectometry, C-OTDR). Modalities of this disclosure may include methods including installation of a distributed fiber optic sensor wound on a reel in the well integrated in a ballast or weight for a seismic optical tool, until complete installation through gravity and / or by a pressurized fluid flow. The method may additionally include reel the distributed optical fiber sensor reel-wound and use the optical fiber as a distributed seismic receiver. In addition, the method may include triggering a seismic signal with a seismic source and recording the seismic signal in the well using coherent time domain reflectometry (C-OTDR). In some modalities, registration can be done with C-OTDR, including phase measurement. Once the distributed optical fiber sensor is installed according to the methods of the present disclosure, surveys can be obtained and processed by several methods, for example, as disclosed in US Patent Application US 2011/10292763 to Coates et al. , commonly attributed to this disclosure.
    [0016] In several surveys and geometries, seismic well surveys were performed by recording seismic signals using a single sensor or a sensor array located in a well that extends from the earth's surface to a formation under the surface. Depending on the particular application, seismic signals can be generated by one or more seismic sources located on the earth's surface, in the well in which seismic signals are detected, in an adjacent well, and / or in the formation involving the well. A wide variety of seismic sources can be used to generate the seismic signals. For example, surface seismic sources can include air guns, accelerated weight drops, vibrating trucks and explosives. Common seismic sources at the bottom of the well may include piezoelectric pulsers, orbital, vertical and radial vibrators, hammers, compressed air guns, lighters, implosive and explosive canisters. In some cases, such as in micro-seismic monitoring or hydraulic fracturing applications, seismic signals are emitted when breaks are generated in the surrounding formation or when the rock on either side of the existing breaks slides in relation to each other. Depending on the particular application in which the monitoring is being carried out, the seismic source may be located in a single location, a limited number of locations (that is, arranged in a single row along the well or on the surface of the soil), or in multiple locations, in order to cover substantially the entire surface of the earth in the vicinity of the well in which the sensors are detecting seismic signals (ie arranged in multiple parallel lines, in multiple lines radiating out from a single location, in a spiral or in a random or pseudo-random manner).
    [0017] As an alternative to a variety of types of known seismic sensors described above, such as hydrophones, geophones, accelerometers or a combination thereof, coupled to electrical components at the bottom of the well that amplify, condition (ie, bandpass filter ) and digitize the electrical signals generated by the sensors in response to the detection of a seismic event, according to the modalities of the present disclosure, seismic signals (including micro-seismic signals) propagating through a formation of earth outside a well can be detected using if one or more vibration sensors distributed by optical fiber (ie fiber optic cable) installed in the well in place of a plurality of distinct sensors installed in various locations in the well. The small diameter of the fiber optic cable (for example, an outer diameter of 125 microns or 250 microns with the insulation around the fiber, or in another example, ranging between 80 and 200 micron fibers and, optionally, should not exceed 500 microns (l / 50 "l / 4 inch or less) allows the installation of a distributed fiber optic sensor inside the drilling column, or in an open and uncovered well. Additionally, a fiber optic seismic signal detection system reduces costly electronics at the bottom of the well. Instead, the electronics for acquiring seismic data from the fiber optic sensor may be located on the surface. The relatively inexpensive fiber optic sensor is installed at the bottom of the well and, due to its nature non-toxic, can be abandoned or left inactive in the well after use. In other words, the fiber optic sensor can be treated as a disposable item.
    [0018] In order to measure seismic signals using a distributed fiber optic vibration sensor, optical pulses can be launched at the distributed fiber optic sensor and reflected or scattered light generated in response to the pulses can be detected over a period of time prolonged. The scattered light that is generated when seismic waves originating outside the well strikes along the length of the distributed fiber optic sensor can provide information about formation characteristics involving the well, including changes in those characteristics over a period of time. Such characteristics may include reservoir extension, geometry and heterogeneity, as well as pore fluid and pressure content, mechanical rock properties, improved oil recovery progress, CO2 sequestration progress, elastic anisotropy parameters, induced break geometry and orientation and intensity of natural rupture. In some modalities, the distributed fiber optic sensor can be removably coupled to the surface electronics to interrogate and acquire data on seismic or micro-seismic events detected by the distributed fiber optic sensor.
    [0019] In some embodiments, the fiber optic cable is wrapped in a storage device such as a spool, producing a distributed fiber optic sensor wound on a spool. Although a spool is described in this simplified embodiment, other embodiments may not be limited to this example. The distributed optical fiber sensor can be contained within an external circumferential compartment in which the central axis of the compartment is parallel to the axis of the tool or well. In addition, the distributed fiber optic sensor can be wrapped around a freewheel pulley, a motor shaft or any of a number of mechanisms used to allow the storage and installation of cable and / or line.
    [0020] In any of the modalities described here, the distributed optical fiber sensor can be a single model fiber or a multiple model fiber, depending on the particular application as well as the particular surface equipment with interrogation unit equipment and data acquisition (for surface equiopment having on interrogation and data acquisition unit, SIDAU) 110 used to collect fiber optic sensor data.
    [0021] Regardless of the location and installation technique used, seismic signals (generated during a seismic survey, for example) can be detected by any one or more of the distributed fiber optic sensors, as shown in FIG. 1,. As an example, any of the following types of seismic survey can be performed with one or more distributed fiber optic vibration sensors being used in place of traditional receiving matrices: Checkshot, Salt-Proximity Surveys, Zero-distance vertical seismic profile (at Vertical Seismic Profile, VSP), VSP Walkabove, VSP Offset, VSP MultiOffset, VSP Walkaway, VSP Walk-Around, VSP Walkaway Multiazimutal, VSP 3D, Transverse well seismic, Hydraulic Fracture Monitoring (in English for Hydrofracturing Monitoring, HFM), Micro-Seismic Monitoring, and Time-lapse drilling Seismic. The surveys mentioned above are provided as examples only and the seismic monitoring techniques and systems described here can be used to monitor seismic signals generated in other scenarios, both stimulated and naturally occurring.
    [0022] FIG. 1 is a schematic cross-sectional illustration of a seismic cross-well system 100 including an optical seismic installation tool 102 including a distributed optical fiber sensor, thereby installed in an uncoated well 103, in accordance with an embodiment of the present disclosure. A fiber optic cable 104 is wound (i.e., on a storage device such as a spool 106), producing a fiber spool wound on a spool. Although a reel 106 is described in this simplified embodiment, other embodiments may not be limited to this example,
    [0023] As shown in FIG. 1, in this embodiment, a fiber optic cable 104 is wound on a spool 106 and attached to a ballast 108 in order to install at a given depth through gravity. The weight of the ballast 108 can be adjusted and the shape configured to facilitate gravity installation. The use of gravity transport may be appropriate for low-deviation wells in which the angle of well 103 allows gravity to overcome frictional forces, thus bringing optical seismic tool 102 to full depth (Total Depth, TD ).
    [0024] In other modalities involving a deviated well (that is, that at least partially deviates from the vertical), a traction motor or the pressurized fluid around it in well 103 can be used to install the optical seismic tool 102. In one embodiment , it is also possible to replace the ballast used to install the fiber through gravity, with an active conveyor including a tractor, propeller or any similar system, to move the conveyor into a bypassed (ie horizontal) well when gravity is inactive to install the fiber. Such devices act on the conveyor, ballast or any other mechanical assembly covering the fiber spool, but not on the fiber itself, such that the fiber cable is installed passively by displacing the conveyor. The length of the fiber extracted from the spool is thus directly related to the displacement of the conveyor, even though the fiber cable is twisted to result in a helical shape when installed in the well.
    [0025] In some cases, fiber optic cable 104 modalities are first wound on a reel that is usually independent. In other words, after the coil has been wound and cured, no previous ones are needed to hold the fiber optic cable 104 on the spool. An example of a cured and wound coil is described in U.S. Patent No. 6,561,488. In such an embodiment, once a fiber optic cable 104 has been installed from such a coil, rewinding back to the spool form can be difficult. Thus, for the modalities of the present disclosure it is possible that the fiber optic cable 104 and ballast portions 108 of the tool may be relatively low value components intended for single use, while the more expensive and long-term electronics remain in the equipment. surface. A weak link, detachable connection or remotely driven or solenoid cutter (among other examples) can be incorporated.
    [0026] Optical fiber wound in a spool installed in the manner described here can be positioned against the well wall as soon as the depth of the optical seismic tool exceeds a few hundred meters. However, the optical fiber can optionally include a coating to make an acoustic coupling more likely, that is, that the optical fiber is positioned against the well wall, based, for example, on surface tension or magnetism. In one embodiment, the optical fiber installation may comprise bending a twisted optical fiber around the spool in order to cause the optical fiber to be placed flat against the well wall. After installation in the well, the optical fiber can take the helical shape of a spring that, after installation in the well, relaxes to touch the well wall. Getting the optical fiber to be placed against the well wall may be desirable in some circumstances or applications. The relatively small mass of optical fiber and the small forces required to extend the optical fiber in response to a seismic wave mean that a touch of low force between the optical fiber and the well wall is sufficient to provide adequate acoustic coupling for seismic waves in the formation.
    [0027] The seismic transverse well system 100 shown in FIG. 1 also includes surface equipment with an interrogation and data acquisition unit (SIDAÜ) 110. The surface equipment may additionally include at least one seismic surface source 112-1 (or a matrix of sources). The seismic transverse well system 100 also includes a seismic source 112-2 in an adjacent well 113. Although FIG. 1 show sources on the surface and in an adjacent well, seismic signals can be generated by one or more seismic sources located on the earth's surface, in the well in which seismic signals are detected, in an adjacent well, and / or in the formation involving the well.
    [0028] Modalities of the optical seismic tool 102 can also be used in pressurized wells. FIG. 2 is a schematic cross-sectional illustration of a seismic cross-well system 200 including an optical seismic tool 102 and a distributed fiber optic sensor installed, thereby, in a drill pipe 205 in pressurized fluid, according to a modality of present disclosure. In such embodiments, the optical seismic tool 102 can be inserted into well 103 through a pressure barrier 209 (such as a discharge outlet, pressure isolation valve or temporary seal) and allowed free fall to a certain depth in well 103 (such as, in some cases, the bottom, or a certain depth under investigation). The reel-wound optical seismic tool 104 can be attached on the surface to the SIDAU 110 and configured to unwind from the optical seismic tool 102 as the optical seismic tool 102 travels downward in the fluid through well 103. The travel speed can be controlled by a combination of ballast weight 108, fluid flow rate in the well (if any), fluid drag based on the shape and area of the optical seismic tool 102, as well as the viscosity of the fluid in well 103 (also referred to as drilling). Depending on the application, the optical seismic tool 102 may include a device, such as a projecting flap, to increase drag and thereby decrease the rate of descent of the optical seismic tool 102.
    [0029] To acquire seismic data, SIDAU 110 converts dynamic voltages per minute of fiber optic cable 104 into an optical signal and from there an electrical signal that can be digitized and stored or further processed to provide a signal in one of the formats accepted by seismic industry, such as LDF file format or SEG-Y file format. An exemplary approach to processing in SIDAU 110 is based on the coherent Rayleigh backscattering principle (sometimes also referred to as coherent Rayleigh noise). In this case, one or more short pulses of coherent light probe is (are) launched (s) to the fiber optic cable 104 and the resulting backscatter with approximately the same optical frequency as the probe pulses is analyzed. Techniques for interrogating the detection fiber are described, for example, in the following patents or patent applications: North American US2012 / 0067118A1, UK GB2 222 247A, PCT International Order Publication No. W02010 / 136810A2, UK, GB2 401 738A, PCT International Order Publication No. W02006 / 048647A2, and US Patent No. 5,194,847). In some modalities, SIDAU 110 can be configured, in one modality, to measure other parameters, such as temperature or voltage profiles.
    [0030] In another embodiment, fiber optic cable 104 may include weak reflectors, such as fiber optic Bragg Grids (in the acronym for Fiber Bragg gratins, FBG), which can be interrogated using various techniques, not the main subject of this disclosure. Such FBG can be used with the twisted fiber technique to determine the pitch of the fiber optic helix and, theoretically, correlate true fiber depth and length, given that the tension exerted on the fiber tends to lengthen the fiber. FBGs can be enrolled during the fiber recording process and form a sensor array, rather than a continuous, fully distributed sensor. A means of interrogating reflective matrices such as this was described earlier, for example, in United Kingdom patent GB2 126 820 or in the international application publication (PCT) No. W02010 / 045286.
    [0031] As shown in FIG. 2, a longer seismic tool 102 with a smaller optical diameter can be connected to a ballast 108 in the shape of a torpedo or dart. Frame pump 214 can be activated to pump the optical seismic tool 102 into the drill pipe 205. In this case, the optical seismic tool 102 is installed by fluid pressure instead of gravity (as was the case in FIG. 1). An approach using pressurized fluid to pump into the optical seismic tool 102 can be used, for example, but not limited to, for deviated wells, up to and beyond horizontal. Other aspects of installing fiber optic cable 104 through optical seismic tool 102 moving below the drill pipe may be similar to those already described in the context of FIG. 1.
    [0032] FIG. 3 shows an illustration of a launching apparatus 300 with an optical seismic tool 102 in a launching position (for example, in a non-pressurized well), according to an embodiment of the present disclosure. In some applications or environments, where it is unacceptable to leave items, such as ballast 108 in the well, the optical seismic tool 102 can be reduced, for example, from a tripod 316 as shown, a suitable means of transport 320, such as slickline, wireline or coil tubing, for example. Centering arms 318 can be used to position the optical seismic tool 102 at the wellhead. Optical seismic tool 102 could optionally be recovered by rewinding transport 320. Fiber optic cable 104 (not shown in FIG. 3, as fiber optic cable 104 does not unwind until implanted in the well) itself it can break and remain in the well, but doable could be obtained.
    [0033] FIG. 4 is an illustration of an optical seismic tool 102 in more detail, then previous figures, according to a modality of the present disclosure, which can be used in any of the modalities illustrated in FIGS. 1 to 3. The optical seismic tool 102 can include a ballast 108 at the bottom or bottom of the well of the tool 102. The ballast 108 can be adjustable in weight, length or both, in a modular way, where weight and length can be added or removed. The weight of the ballast 108 and the length can be selected for the well deviation in which it will be used, the density of the mud or other fluids in the well, the flow rate of the planned fluid in the well and the descent speed, intended for the seismic tool optics 102.
    [0034] Ballast 108 can be made of a material that is natural, in an incarnation, allowing the abandonment of ballast 108 in the well after the completion of an investigation, such as sands, elemental metals such as aluminum and the like. In one embodiment, the material for ballast 108 may be cement. In yet another embodiment, ballast 108 can be made of a material designed to dissolve or be absorbed in the liquid or mud in the well, for example, a stone salt or fine-grained lead shot, joined together with soluble glue, or other material that decomposes or melts under rock bottom conditions after a specified period of time.
    [0035] Ballast 108 is coupled through a locking mechanism 422, for example, a groove, to a fiber spool 106. The fiber spool 106 contains the optical fiber wound as described above, wound on a spool or cured in a coiled shape on the fiber spool 106. After implantation, the fiber optic cable 104 unwinds on top of the optical seismic tool 102 through a nozzle 424 (i.e., a fishing head or nozzle). As noted above, the fiber optic cable may have a protective, adhesive, and / or magnetic coating.
    [0036] Referring now to FIG. 5 is a flowchart shown outlining a method 500 for installing an optical seismic tool in a well in a seismic well survey. The method begins with a dissociable coupling 526 seismic optical instrument on the surface for the surface equipment. The surface equipment may include an optical source (not shown separately) that launches optical pulses for the fiber distributed optical sensor, as well as the SIDAU 110. The optical seismic tool consists of a coil of optical fiber coupled to a ballast of Adjustable size and a mechanism that couples to the surface equipment, such as a latch, fishing head, mouthpiece and the like.
    [0037] The method continues with installation 528 the optical seismic tool through one of gravity and a force of a pressurized fluid, thus unwinding the fiber optic cable at the bottom of the well. The method continues to generate a 530 acoustic force coupling between the fiber optic cable and the well, such that the seismic waves traveling in the formation over the well can be measured by the fiber optic cable. Generating acoustic coupling contact between the fiber optic cable and the well walls can include coupling the fiber optic to the well walls through an adhesive coating, a magnetic coating and / or helical outward force caused by the relaxation of the optical fiber coiled. In a deviated well, generating the acoustic coupling contact force could also include forces caused by gravity as the coiled optical fiber relaxes against the bottom walls of the well.
    [0038] The method can optionally include decoupling the optical seismic tool from the surface acquisition unit with an integrated decoupler, which can cut, twist or otherwise separate the fiber-optic cable from SIDAU 110.
    [0039] The method can optionally include more by deploying the optical seismic tool to a first depth at a rate at least in part based on the adjustable size of the reactor coupled to the distributed fiber optic sensor.
    [0040] The method can optionally include more by implanting the optical seismic tool to the first depth through fluid pressure at a rate based on a flow rate in the well, liquid friction based at least in part on the shape or area seismic optical tool and fluid viscosity in the well.
    [0041] The modalities of the present disclosure can be directed to hydrocarbon production wells, injection wells to improve hydrocarbon recovery, geothermal wells for energy extraction or storage, CO2 sequestration wells and wells drilled for the specific purpose seismic monitoring. In addition, distributed fiber optic vibration sensors can be implanted in several wells, in the vicinity of a well that contains a seismic source so that they can carry out various seismic surveys of cross wells can be conducted. Likewise, several wells in the vicinity can be instrumented during the performance of almost any of the drilling seismic surveys discussed in this document. In addition, several wells around a well subjected to hydrofracture stimulation may contain fiber optic vibration sensors for detecting seismic signals generated as a result of the hydraulic fracturing process.
    [0042] While the disclosure has been disclosed with respect to a limited number of modalities, those skilled in the art, having the advantage of this disclosure, will appreciate numerous modifications and variations therefrom. While disclosure has been described in the context of rock bottom tool applications, the disclosure apparatus can be used in many applications.
    [0043] 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 through a or more elements "; and the term "set" is used to mean "one element" or "more than one element". As used herein, the terms "up" and "down", "upper" and "lower", "upward" and downward "," upstream "and" downstream "," above "and" below "; and other similar terms indicating the relative position above or below a given point or element are used in this description to more clearly describe some modalities of the present disclosure.
    [0044] Although some example modalities have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example modalities without departing materially from this disclosure. Accordingly, all of these changes are intended to be included in the scope of this disclosure, as defined in the following claims. In the claims, the half-plus-function clauses are intended to cover the structures described in this document as it performs the aforementioned function and not simply structural equivalents, but also equivalent structures. Thus, although a nail and a screw may not be structural equivalents in what a nail uses a cylindrical surface to fix the wooden pieces, while a screw uses a helical surface, in the setting environment of wooden parts, a nail and a screw they can be equivalent structures. It is the express intention of the claimant not to invoke 35 U.S.C §112, paragraph 6 for any limitations of any of the claims in this document, except for those in which the claim expressly uses the words "means for" in conjunction with an associated function.
    [0045] The preferred aspects and modalities were chosen and described to better explain the principles of present disclosure and their practical application. The foregoing description is intended to allow others skilled in the art to make better use of methods and apparatus in various modalities and with various modifications as they are suited to the specific use contemplated. In addition, the methods can be programmed and saved as a set of instructions, which, when executed, by executing the methods described in this document. It is intended that the scope of the present methods and apparatus be defined by the following claims.
    权利要求:
    Claims (17)
    [0001]
    1. OPTICAL SYSMIC TOOL (102), characterized by the fact that it comprises: a reel of optical fiber cable coupled to a ballast (108) of adjustable dimensions and a means of coupling to the surface equipment comprising an optical source; wherein the ballast (108) of adjustable dimensions comprises a tooth an adjustable weight and an adjustable length; wherein the ballast (108) of adjustable dimensions is adjustable based on mud density, well deviation and a certain rate of descent of the optical seismic tool (102); where the fiber optic cable spool unwinds through gravity after the installation of the ballast (108) of adjustable dimensions in a well, the unwinding generating an acoustic coupling force between the fiber optic cable (104) and the well ( 103).
    [0002]
    2. Optical seismic tool (102) according to claim 1, characterized in that the fiber optic cable spool is coupled to a well-above side of the ballast (108) of adjustable dimensions.
    [0003]
    3. Optical seismic tool (102), according to claim 1, characterized by the fact that the optical fiber cable (104) further comprises one of: a magnetic coating, an adhesive coating and a protective coating.
    [0004]
    4. Optical seismic tool (102), according to claim 1, characterized by the fact that the acoustic coupling force is generated by one of: an adhesive coating, a magnetic coating, an outward helical force caused by the relaxation of the cable optical fiber (104), and any combination thereof.
    [0005]
    5. Optical seismic tool (102), according to claim 1, characterized by the fact that the fiber optic cable spool unwinds through gravity, as well as a force applied by a pressurized fluid after the installation of the ballast (108 ) of adjustable dimensions in the well.
    [0006]
    6. Optical seismic tool (102), according to claim 1, characterized by the fact that the ballast of adjustable dimensions comprises one of a natural material dissoluble in mud selected from a group consisting of aluminum, cement, salt and a metal.
    [0007]
    7. OPTICAL SEISMIC LIFTING SYSTEM, characterized by the fact that it comprises: a surface control and collection unit comprising a controller and an optical source; a seismic source disposed on the surface or in a well coupled to the surface collection and control unit that generates seismic signals when activated by the surface collection and control unit; and an optical seismic tool (102) removably coupled to the surface collection and control unit, comprising: a fiber optic cable reel coupled to a ballast (108) of adjustable dimensions and a means of coupling to the surface equipment comprising an optical source; where the fiber optic cable spool unwinds through gravity after the installation of the ballast (108) of adjustable dimensions in the well, the unwinding generating an acoustic coupling force between the fiber optic cable (104) and the well (103 ), in which the surface control and collection unit, after installing an optical seismic tool (102) in the well (103), obtains, through a distributed optical fiber sensor, several optical measurements related to a characteristic of a among: 1) the well and 2) a formation through which the well is drilled, when the distributed optical fiber sensor is deformed by seismic signals.
    [0008]
    8. Seismic lifting optical system, according to claim 7, characterized by the fact that the ballast (108) of adjustable dimensions comprises one among adjustable weight and adjustable length.
    [0009]
    9. Seismic survey optical system, according to claim 8, characterized by the fact that the ballast (108) of adjustable dimensions is adjustable based on mud density, well deviation and a certain rate of descent of the optical seismic tool .
    [0010]
    10. Seismic survey optical system according to claim 7, characterized by the fact that the fiber optic cable spool is coupled to a well-side of the ballast (108) of adjustable dimensions.
    [0011]
    11. Seismic survey optical system, according to claim 7, characterized by the fact that the optical fiber cable (104) further comprises one of: a magnetic coating, an adhesive coating and a protective coating.
    [0012]
    12. Seismic survey optical system, according to claim 7, characterized by the fact that the acoustic coupling force is generated by one of: an adhesive coating, a magnetic coating, an outward helical force caused by the relaxation of optical fiber, and any combination thereof.
    [0013]
    13. Seismic survey optical system, according to claim 7, characterized by the fact that the fiber optic cable spool unwinds through gravity, as well as a force applied by a pressurized fluid after the installation of the ballast (108) of adjustable dimensions in the well (103).
    [0014]
    14. METHOD OF INSTALLING OPTICAL SEISMIC TOOL IN A WELL IN A SEISMIC LIFTING OF THE WELL, characterized by the fact that it comprises: the separate coupling of an optical seismic tool (102) on the surface to surface equipment comprising an optical source that launches optical pulses in an optical seismic tool (102); wherein the optical seismic tool (102) comprises a fiber optic cable spool coupled to a ballast (108) of adjustable dimensions and a means of coupling to the surface equipment; the installation of the optical seismic tool (102) through one of gravity and a force of a pressurized fluid, thus unwinding the fiber optic cable spool, in which the optical seismic tool (102) is installed in a first depth through pressure fluid at a rate based on one of: well flow rate, fluid drag based, at least in part, on the shape or area of the seismic optical tool and fluid viscosity in the well; and the generation of an acoustic coupling force between the fiber optic cable (104) and the well (103).
    [0015]
    15. Method, according to claim 14, characterized by the fact that it also comprises the decoupling of an optical seismic tool (102) from the surface collection unit.
    [0016]
    16. Method, according to claim 14, characterized by the fact that it also comprises the installation of the optical seismic tool (102) in a first depth at a rate based, at least in part, on the adjustable dimensions of the ballast coupled to a sensor distributed optical fiber.
    [0017]
    17. Method, according to claim 14, characterized by the fact that the generation of the acoustic coupling force between the optical fiber cable (104) and the well walls further comprises the coupling of the optical fiber to the well walls through one or more of: an adhesive coating, a magnetic coating, and helical outward force caused by the relaxation of optical fiber wound on a spool.
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    US9798023B2|2017-10-24|
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    法律状态:
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2020-02-27| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-06-23| B09A| Decision: intention to grant|
    2020-11-10| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 04/01/2013, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    EP12250004|2012-01-06|
    EP12250004.4|2012-01-06|
    PCT/US2013/020406|WO2013103908A1|2012-01-06|2013-01-04|Optical fiber well deployment for seismic surveying|
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