• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
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    • 专利摘要:
    INTEGRATED FIBER OPTIC CABLE, FIBER OPTIC MONITORING SYSTEM FOR A WELL SITE, AND METHOD FOR MONITORING A WELL SITE. Fiber optic integrated monitoring techniques for a well site are provided. An optical fiber cable is provided with a tubular housing having a channel and a plurality of slots, a plurality of optical fibers being floatable in the channel for measuring at least a first wellsite parameter, and a plurality of fixed optical fibers positionable in each of the slots to measure at least a second well location parameter. The tubular housing is positionable in a wellbore adjacent to a pipe in it. Pairs of fixed and floating optical fibers can be spliced together to perform Stimulated Brillouin measurements.
    公开号:BR112013022777B1
    申请号:R112013022777-0
    申请日:2012-03-08
    公开日:2021-04-20
    发明作者:Jeremiah Glen Pearce
    申请人:Shell Internationale Research Maatschappij B. V；
    IPC主号:
    专利说明:

    Technical Field of the Invention
    [0001] The present invention refers, in general, to techniques for performing operations in a well site. More specifically, the present invention relates to techniques and hardware, such as optical fibers, for monitoring a well site. Fundamentals of the Invention
    [0002] In the production of hydrocarbons from underground reservoirs, oil main chamber tools are typically employed from a surface location and to a wellbore to reach underground reservoirs. Once the well is formed, casings can be cemented in place within the wellbore, and this is completed to start producing fluid from the reservoir. Pipes (or ducts) can be placed in the wellbore to transfer fluid from the reservoir to the surface.
    [0003] During well-site operations, devices are often positioned in the wellbore to monitor various conditions. In some cases, optical fibers can be placed in the hole to monitor various conditions at the well site. Examples of optical fiber techniques are described in patents US7,409,858, US7,254,289, US7,245,791 and US6. 854,327.
    [0004] Despite the development of fiber optic techniques, there remains a need to provide advanced techniques to effectively monitor conditions at the well site. It may be desirable to provide techniques that provide better monitoring, preferably in three-dimensional space. It may still be desirable to provide techniques that provide guidance information during monitoring. Techniques may involve one or more of the following, among others: monitoring a variety of parameters, flexible operation, adaptability to a desired well site operation, protected configuration, enhanced measurement, etc. The present invention is directed to meeting such needs in the art. Invention Summary
    [0005] In one embodiment, the invention relates to an integrated fiber optic cable to a well site, having a pipe positionable in a wellbore that penetrates into an underground formation. As used here, “embedded” fiber optic cable is one that integrates more than one fiber optic measurement capability, such as DAS, DTS, DPS, etc. on a single cable. The integrated fiber optic cable includes a tubular housing having an inner channel and a plurality of outer slots or channels, a plurality of optical fibers floating in the housing for measuring at least a first wellsite parameter, and at least one optical fiber fixedly supported on the housing to measure at least a second well location parameter.
    [0006] The tubular housing preferably has at least one positionable flat surface adjacent to the pipe, whereby an orientation of the tubular housing against the pipe is readily maintained. The tubular housing can have a triangular, quadratic or rectangular cross section. At least one of the plurality of floating optical fibers can be coupled to a sensor to measure the wellsite parameter. Pairs of fixed and floating optical fibers can be selectively grouped, whereby an optical loop is formed to transmit between them. Fixed optical fibers can measure strain using one or more interferometric techniques of stimulated scattering of Brillouin or fiber Bragg Grids, or others, and/or be used for distributed acoustic sensing (DAS) measurements. A gel can be used to load the channel. Fixed optical fibers can be adhered in a plurality of slits. At least first and second wellsite parameters can comprise pressure, temperature, acoustics, curvature, bending and/or strain.
    [0007] In another aspect, the invention may refer to an integrated fiber optic monitoring system for a well site, having a pipe positionable in a wellbore extending to an underground formation. The integrated fiber optic monitoring system may include at least one sensor, at least one surface interrogation unit, and an integrated fiber optic cable positionable around the tubing. The integrated fiber optic cable preferably but not necessarily includes a tubular housing having an inner channel and a plurality of outer slots, a plurality of floating optical fibers positionable in the channel for measuring at least a first wellsite parameter, and a plurality of optical fibers fixedly positionable in each of the plurality of slits for measuring at least a second wellsite parameter.
    [0008] The integrated fiber optic cable monitoring system can also have a plurality of splices to selectively splice fixed and floating optical fiber pairs together, a spool to install the fiber optic cable in the wellbore, and/ or at least one sensor coupled to at least one of the floating optical fibers.
    [0009] In yet another aspect, the invention may refer to a method of monitoring a well location. The method involves positioning an integrated fiber optic cable at the wellsite, measuring at least one wellsite parameter with the fixed and floating optical fibers, and transmitting the measured wellsite parameter to a surface interrogation unit .
    [00010] The method may further involve splicing a plurality of the at least one of the integrated fiber optic cables together, forming an optical loop by selectively splicing pairs of the plurality of fixed and floating optical fibers, determining strain using Stimulated Brillouin techniques, determining shaping the cable from the plurality of fixed optical fibers, and/or coupling a sensor to at least one of the plurality of fixed optical fibers. Brief Description of Drawings
    [00011] In order that the above-mentioned characteristics and advantages of the present invention may be understood in detail, a more particularized description of the invention, summarized above, can be obtained by referring to its embodiments illustrated in the attached drawings. It should be noted, however, that the attached drawings only illustrate typical embodiments of this invention should therefore not be considered limiting of its scope, since the invention may admit other equally functional embodiments. Figures are not necessarily to scale or schematic, for reasons of clarity and brevity.
    [00012] Figure 1 is a schematic view, partially in cross section, of a well site having an integrated fiber optic cable monitoring system according to the invention.
    [00013] Figure 2 is a schematic view of a portion of the integrated fiber optic monitoring system of Figure 1, illustrating its integrated fiber optic cable.
    [00014] Figure 3A is a cross-sectional view of the integrated fiber optic cable of figure 2 taken along line 3A-3A.
    [00015] Figure 3B is a cross-sectional view of an alternative integrated fiber optic cable.
    [00016] Figure 4 is a flowchart of a monitoring method. Detailed Description of the Invention
    [00017] The following description includes exemplary apparatus, methods, techniques, and instruction sequences that incorporate techniques of the present invention. However, it should be understood that the described embodiments can be practiced without these specific details.
    [00018] Figure 1 illustrates a wellsite 50 with an integrated fiber optic monitoring system 100. The wellsite 50 has a production pipeline 102 extending into a wellbore 104 to reach an underground reservoir 106. production pipe 102 can be positioned within a casing 108 applied to the wellbore 104.
    [00019] The integrated fiber optic monitoring system 100 includes an integrated fiber optic cable 110 installed in the wellbore 104. As shown in Figure 1, the integrated fiber optic cable 110 can be installed in the wellbore 104 from of a spool 112. As further shown in Figure 1, the integrated fiber optic cable 110 can be positioned between the production tube 102 and the sheath 108. In some applications, the fiber optic cable 110 can be helically positioned around the tubing. When concentric pipes are provided, one or more fiber optic cables 110 can be positioned around one or more pipes and can be positioned on an inner wall or outer wall of the tubular, or in the annulus between concentric tubulars. Fiber optic cables 110 can be coupled to the tubing using, for example, cement, adhesives, connectors or the like.
    [00020] Fiber optic monitoring system 100 can be positioned around various wellsite structures, such as production pipeline 102 of figure 1. Fiber optic monitoring system 100 can also be used with other pipeline (or production or non-production tubulars), such as a well casing, an unperforated tubular, a perforated tubular, a drill pipe, a joint, a production pipe, a casing pipe, a tubular filter, a filter sand, a gravel pack filter, combinations thereof, and the like. The tubing can be formed from steel or other materials.
    [00021] An interrogation (or data acquisition) unit 19 can be coupled to the fiber optic monitoring system 100 to monitor a variety of well site parameters. The interrogation unit 109 can be used to receive signals (e.g., data) from the fiber optic cable 110. The interrogation unit 109 can be provided with communication, processing, memory interface and other components to manipulate the data.
    [00022] The fiber optic monitoring system 100 can be used during production and/or non-production well site operations, such as injection, depletion, completion, cementation, gravel filling, fracturing, production, stimulation, flooding, a miscible gas process, inert gas injection, carbon dioxide injection, alternate gas-water process, liquefied petroleum gas injection, chemical injection, thermal recovery, cyclic steam injection, steam injection, fire injection, advanced combustion, dry combustion, well test, throughput test, potential test, pipe pressure, casing pressure, bottom hole pressure, drawdown, combinations thereof, and the like. Fiber optic monitoring system 100 can be configured to investigate problems inside the well (eg those indicated by changes in production) such as cross flow, premature eruption, casing leaks, fluid migration, corrosion, pipe leaks, plug leaks, piped cement, other cement quality problems, burst joint leaks, loss zones, combinations thereof, and the like. Fiber optic monitoring system 10 can also be used to facilitate the identification of fluid inlet/outlet points or intervals, the flow rate at these points, the type of fluid at such points, and the origin of the fluids reaching the well. Fiber optic monitoring system 100 can also be configured to investigate the health of a well as part of a routine maintenance operation.
    [00023] Figure 2 shows a schematic view of a portion of the fiber optic monitoring system 100 of figure 1 in more detail. As shown in this view, fiber optic cable 110 includes an elongated tubular housing 214 having an inner longitudinal channel 216 and outer longitudinal slots 218. Channel 216 and slots 218 of housing 214 provide passages for housing a plurality of optical fibers 220a-b , 222a-c. Housing 214 is preferably made of a strong material such as metal (eg steel, INCONEL™ etc.) or other material capable of protecting the optical fibers in the wellbore.
    [00024] The fiber optic cable 110 is preferably configured with multiple optical fibers arranged in parallel along the length of the cable to provide monitoring of various wellsite parameters. Fiber optic cable 110 preferably includes a plurality of both floating (eg 220a-b) and fixed (eg 222a-c) optical fibers for measuring a variety of wellsite parameters in a single cable (or fiber optic cables connected in series as shown in figure 2). In the illustrated embodiments, a plurality of floating optical fiber 220a-b is disposed in channel 216 and a plurality of fixed optical fibers 222a-c is disposed in an outer channel. Measurable well location parameters can include, for example, borehole parameters (e.g., curvature, bending, deformation (e.g., axial) etc.) along the wellbore.
    [00025] Although the floating optical fibers are arranged in the inner channel and the fixed optical fibers are each arranged in one of the outer slots in the illustrated embodiment, it will be understood that other configurations are also suitable. As an example only, there may be an internal channel housing the floating optical fibers and a second internal channel housing the fixed optical fibers, the floating optical fibers can be arranged in external channels or slots and fixed optical fibers in an internal channel, or all fibers could be in a single channel or slit.
    [00026] Optical fibers can be any one capable of transmitting data and/or communication signals through the wellbore. Examples of optical fibers and/or cables usable with the fiber optic monitoring system are available from OMNISENS™, located at 3 Riond Bosson, CH-1110 Morges, Geneva, Switzerland.
    [00027] Still referring to Figure 2, a preferred embodiment of optical fiber 110 has a plurality of floating optical fibers 220a, 220b positioned in channel 216, and a plurality of floating optical fibers 222a, 222b, 222c positioned in slots 218 Optical fibers 220a-b, 222a-c preferably extend along the length of housing 214. A splice block 224 is provided between a series of housings 214. A splice 226a is provided to couple optical fibers from a housing 214 to another. In this way, a series of fiber optic cables 110 can be connected to extend across the length of the well site. Fiber optic cables 110 can be spliced together during installation or pre-assembled. Once fiber optic cables 110 are introduced into the well, the cable can be cut and spliced to the surface, for example, for coupling to interrogation unit 109, as shown in figure 1.
    [00028] Still referring to figure 2, a termination block can also be provided at the end of the sequence of accommodations. Splices 222a-c are provided to optically couple optical fibers to complete the communication link between them. As shown, fixed optical fibers 222a, 222b are paired, and floating optical fiber 220b and fixed optical fiber 222c are paired. Several fiber pairs can be provided.
    [00029] Floating fiber optic 220a is coupled to a sensor (or meter) 230 to monitor hole interior parameters. Fiber optic monitoring system 100 may have one or more sensors 230 to monitor borehole parameters such as temperature, pressure, acoustics, etc. Sensor 230 may be any device capable of monitoring desired downhole parameters, such as pressure gauge, temperature gauge, gratings, strain gauge, piezo resistor, blade gauge, or other device positionable within the hole.
    [00030] Figure 3A is a cross-sectional view of fiber optic cable 110 of figure 2, taken along line 3A-3A. As shown in this view, housing 214 has a triangular section with a plurality of flat surfaces 332. Flat surfaces 2332 can be used to facilitate positioning fiber optic cable 110 against a pipe, and to determine azimuthal orientation around it. Flat surfaces 332 preferably prevent rotation of fiber optic cable 110 to maintain a constant orientation around the tubing along the length of the wellbore. Figure 3B shows an alternative fiber optic cable 110' having a housing 214' with a square shape. As shown by Figures 3A and 3B, the housing can have various configurations such as triangular, square or other shapes to maintain the orientation of the flat surfaces 332 against the piping. A rectangular shape can allow for greater cable thickness, and a larger cross-sectional area to accommodate additional fibers.
    [00031] One or more floating optical fibers (eg 222a-b) may be provided. Any number of optical fibers may be provided, such as optical fibers 222a-g shown in Figure 3A, or optical fibers 222a-k in Figure 3B. These floating optical fibers can be coupled to sensors or paired with other optical fibers, as shown in figure 2.
    [00032] In some embodiments, optical fibers 222a-k may float within a gel 334 in channel 216. Gel 334 may be any material capable of supporting the optical fibers and/or facilitating monitoring (e.g., acoustic measurement ) by optical fibers. Gel 334 can be positioned in the housing to house floating optical fibers (eg, 220a-g, 220a-k) to provide distributed measurements (eg, a distributed temperature sensing (DTS) system, a distributed temperature sensing system. pressure (DPS), a distributed acoustic sensing system (DAS), communication lines, and/or fibers for splicing in single-point meters (eg, pressure, temperature gauges, grids, strain gauges, piezo resistors, gauges blade etc.).
    [00033] 220a-k floating optical fibers can be configured to operate as a DTS, DPS and/or DAS system. Floating optical fibers 220a-k are positioned within housing 214 to take measurements (e.g., temperature and pressure) along the length of coating 108 independently of fixed optical fibers 222a-c. For example, internal pressure of fluid levels and annular pressure at the wellhead can be measured with a pressure gauge 230 positioned inside casing 108 (figure 1). Alternatively other independent means of measuring or calculating temperature and pressure can be used.
    [00034] Still referring to figures 3A and 3B, the fiber optic cable 110 may also be provided with one or more slots 218 having fixed optical fibers (eg 222a-c) disposed therein. As shown in Figure 3A, three slits 218, with an optical fiber 222a-c attached to them, are provided. As shown in Figure 3B, an alternative embodiment having four slots 218 with a corresponding attached optical fiber 222a-d therein can be provided. Fixed optical fibers 222a-d can be bonded in position within slots 218 with glue or adhesive. Fixed optical fibers 222a-d can be rigidly coupled to obtain coupling with good strain/acoustic transfer. One or more slots 218 with an optical fiber 222a-d attached to them can be used. Fixed optical fibers 222a-d can be used to measure various well location parameters such as curvature, bending, strain (eg axial) etc.
    [00035] When three or more slits 218 with fixed optical fibers 222a-c are positioned around fiber optic cable 110 to measure strain, the shape of fiber optic cable 110 can be derived by using optical signals transmitted to the fibers 222a-c. Fixed 222a-c optical fibers can be used to measure, for example, pipe deformation over a range of depths across the entire wellbore. When multiple fixed optical fibers are used to measure strain, a 3D image can be obtained showing the cable shape and strain around the wellbore.
    [00036] Various techniques can be used to measure various parameters determined by optical fibers. For example, conventional distributed strain measurement techniques such as Brillouin Scattering and Fiber Bragg Grid (FBG) measurements can be used with this configuration, and the rigid coupling of the fiber to the cable should also enhance the acoustic response of a measurement of DAS. Although FBGs can be used in conjunction with wavelength division multiplexing (WDM) and/or frequency division multiplexing (FDM) for strain sensing, Brillouin's stimulated system, such as the one manufactured by OMNISENS™, can also be used . Furthermore, although FBGs with FDM can be used to obtain greater spatial resolutions and to detect the presence of localized events, Brillouin stimulated systems can provide greater extents of enhanced sensing.
    [00037] Various fiber optic configurations can be used to enhance monitoring. Additional fixed optical fibers can be used to provide some redundancy. An even number of fixed optical fibers can be spliced together to form fiber loops for Brillouin stimulated systems. Fixed optical fibers and charged floating optical fiber may have different sensitivities to different types of acoustic modes and waves (shear versus compressive). Measurements made by the various optical fibers can be compared and analyzed. IF interrogated simultaneously, these modes can be decoupled and used for seismic logging applications.
    [00038] Referring to figures 2, 3A and 3B, when using a Brillouin paced system, a loop configuration (the ability to access both ends of the fiber with the instrument) may be required. The number of fibers used in the fiber optic cable 110 proposed in this invention can be minimized by splicing the strain transfer fiber pairs at the end of the fiber optic cable 110, or by connecting all the fixed optical fibers 222a-c together. by splicing in termination block 228. During installation, fiber optic cable 110 may be shipped with the appropriate optical fibers spliced together at the end of fiber optic cable 110 by one or more splice blocks 224. 110 is then passed as a standard line and control on the piping (eg production piping or outside casing, depending on the application). After the fiber optic cable 110 is completely routed into the well, it can be cut and spliced with appropriate connectors in the wellhead.
    [00039] The interrogation unit 109 can be positioned on the surface (on or off-site) to measure parameters such as temperature, strain and acoustics. For strain measurements, each fixed optical fiber or fiber pairs can be interrogated separately. An optical switch (not shown) can be used to minimize the number of interrogation units 109.
    [00040] Figure 4 is a flowchart illustrating a method (400) of monitoring a well site. The method involves placing (450) a fiber optic monitoring system around a pipe in a wellbore of the well site, forming (452) an optical mesh by selectively coupling pairs of fixed optical fibers and floating optical fibers , measuring (454) at least one wellsite parameter with the fixed optical fibers and the floating optical fibers, and transmitting (456) the measured wellsite parameter to a surface interrogation unit. Optical mesh can be used to determine strain using Stimulated Brillouin techniques.
    [00041] The method (400) may further involve additional steps, such as splicing (458) a plurality of integrated optical fiber cables, determining (460) a cable shape from the plurality of fixed optical fibers, and/or coupling (462) a sensor to at least one of the plurality of fixed optical fibers. Splicing may involve splicing pairs of the plurality of fixed optical fibers together and/or splicing at least one of the floating optical fibers to at least one of the fixed optical fibers.
    [00042] It should be appreciated by one skilled in the art that the techniques disclosed herein can be implemented programmatically, using conventional computers, and/or for automated (stand-alone) applications using software configured with algorithms to perform the desired functions. Aspects of the invention can also be configured to perform the techniques described using appropriate hardware or software and/or an extended communication network (e.g. wireless, internet, satellite, etc.).
    [00043] Although the present report describes specific aspects of the invention, numerous modifications and variations will become apparent to one skilled in the art after examining the report, including the use of functional and/or structural substitutes equivalent for elements described herein. For example, aspects of the invention may be provided with varying amounts of optical fibers (floating and/or radial). Furthermore, although in-hole applications of the fiber optic system are disclosed and described, it is to be understood that the systems and methods described herein can be used in surface applications as well. All similar variations apparent to one skilled in the art are intended to fall within the scope of the invention as defined by the appended claims.
    [00044] Multiple instances can be provided for components, operations or structures described here as a single instance. In general, structures and functionality presented as separate components in the example configurations can be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component can be implemented as separate components. These and other variations, modifications, additions and improvements may fall within the scope of the invention.
    权利要求:
    Claims (15)
    [0001]
    1. Integrated fiber optic cable (110) to a wellsite having tubing positionable in a wellbore (104) extending into an underground formation, comprising: a tubular housing (214) having an inner longitudinal channel (216) and a plurality of external longitudinal slots (218), the tubular housing (214) being positionable in the wellbore (104) adjacent to the pipe; a plurality of floating optical fibers (220) for measuring at least a first wellsite parameter; and, a plurality of fixed optical fibers (222) for measuring at least a second well-site parameter, characterized in that the floating optical fibers (220) are floating positionable in the channel (216) and the floating optical fibers (220) are fixedly positionable in the slots (218).
    [0002]
    2. Cable according to claim 1, characterized in that the tubular housing (214) has at least one flat surface (332) positionable adjacent to the pipe, whereby an orientation of the tubular housing against the pipe is maintained.
    [0003]
    3. Cable according to any one of claims 1 or 2, characterized in that at least one fiber of the plurality of floating optical fibers (220) is coupled to a sensor (230) to measure the at least one location parameter of pit.
    [0004]
    4. Cable according to any one of claims 1 to 3, characterized in that pairs of the plurality of fixed optical fibers (222) and the plurality of floating optical fibers (220) are selectively coupled, where an optical mesh is formed to transmission between them.
    [0005]
    5. Cable according to any one of claims 1 to 4, characterized in that the plurality of fixed optical fibers (222) measures at least one wellsite parameter using one of the Stimulated Brillouin, Fiber Bragg Grids techniques , DAS measurements and combinations thereof.
    [0006]
    6. Cable according to any one of claims 1 to 5, characterized in that the floating optical fibers (220) are arranged in a gel (334) and the fixed optical fibers (222) are adhered to the housing (214).
    [0007]
    7. Cable according to any one of claims 1 to 6, characterized in that the first and second well location parameters are selected from the group consisting of pressure, temperature, acoustics, curvature, bending, strain and combinations thereof .
    [0008]
    8. Fiber optic monitoring system for a well site, comprising: a fiber optic cable (110) comprising: a tubular housing (214) having an inner longitudinal channel (216) and a plurality of outer longitudinal slots (218) , the tubular housing (214) being positionable at the well location; a plurality of floating optical fibers (220) for measuring at least a first wellsite parameter; and a plurality of fixed optical fibers (222) for measuring at least a second wellsite parameter; the fiber optic monitoring system further comprising: at least one surface interrogation unit (109) attachable to the fiber optic cable (110) for sending optical signals to at least one of the floating optical fibers (220) and fixed optical fibers ( 222) and receiving a feedback signal indicative of a measured well location parameter, characterized in that the floating optical fibers (220) are float positionable in the channel (216) and the floating optical fibers (220) are positionable fixedly in the slots (218).
    [0009]
    9. System according to claim 8, characterized in that it further comprises a plurality of splices to selectively splice together pairs of the plurality of fixed optical fibers (222) and the plurality of floating optical fibers (220).
    [0010]
    10. Method for monitoring a well site, comprising the steps of: a) positioning a fiber optic cable (110) at the well site, the fiber optic cable (100) comprising: a tubular housing (214) having a channel longitudinal inner (216) and a plurality of outer longitudinal slots (218), the tubular housing (214) being positionable in the wellbore adjacent to the pipe; a plurality of floating optical fibers (220) for measuring at least a first wellsite parameter; and, a plurality of fixed optical fibers (222) for measuring at least a second wellsite parameter; b) measuring at least one wellsite parameter by sending optical signals to at least one of the floating optical fibers (220) and fixed optical fibers (222) and receiving a feedback signal indicative of a measured wellsite parameter; and, c) transmitting the measured well location parameter to a surface interrogation unit (109); the method characterized in that the floating optical fibers (220) are floating positionable in the channel (216) and the floating optical fibers (220) are fixedly positionable in the slots (218).
    [0011]
    11. Method according to claim 10, characterized in that the optical fiber cable includes an optical mesh formed by selectively splicing pairs of the plurality of fixed optical fibers (222) and the plurality of floating optical fibers (220).
    [0012]
    12. Method according to any one of claims 10 or 11, characterized in that it further comprises determining a cable shape from the measured well location parameter.
    [0013]
    13. Method according to claim 12, characterized in that fixed optical fibers (222) and floating optical fibers (220) have different sensitivities to different types of modes and acoustic waves, further comprising the step of comparing measurements made by fixed optical fibers (222) and floating optical fibers (220).
    [0014]
    14. Method according to claim 13, characterized in that it further comprises the step of interrogating the fixed optical fibers (222) and the floating optical fibers (220) simultaneously, decoupling the optical signals received as a result of the interrogation, and using the uncoupled signals to obtain a seismic profile.
    [0015]
    15. Method according to claim 14, characterized in that it further comprises the step of performing distributed acoustic sensing using one of the fixed optical fibers (222).
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    法律状态:
    2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-10-15| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2021-02-09| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2021-04-20| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 08/03/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161450942P| true| 2011-03-09|2011-03-09|
    US61/450,942|2011-03-09|
    PCT/US2012/028199|WO2012122336A1|2011-03-09|2012-03-08|Integrated fiber optic monitoring system for a wellsite and method of using same|
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