巴西专利BR112013007142B1 METHOD AND SYSTEM FOR MONITORING THE LINEARITY OF A WELL BOTTLE PUMPING SYSTEM SET

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专利摘要:
linearity monitoring system for downhole pumping systems during installation and related methods. systems (30), programs and methods for monitoring the linearity of a well-bottom pumping system set (31) during installation inside a hole (29) of a well structure (23) positioned (20) to extract hydrocarbons from an underground reservoir (21) and select an ideal operational position for a set of downhole pumping system (31) inside the bore (29) of the structure (23) are provided. various modalities of the systems (30) allow an operator to ensure that an engine (35, 36) and a pump from a downhole pumping system assembly (31) are installed in an ideal position in a well (20) , ensuring an alignment of the pump stages (39), structure (41) and motor structure (47) .Alignment and linear age of the pump (33) and motor (35, 36) can be crucial for life pump (33) and / or motor (35, 36).
公开号:BR112013007142B1
申请号:R112013007142-7
申请日:2011-09-21
公开日:2020-09-24
发明作者:Robert M. Harman；Earl B. Brookbank；Brooks A. Childers；Philippe J. Legrand；Malcolm S. Laing；Roger G. Duncan；Suresha R. O'bryan；Ketankumar K. Sheth
申请人:Baker Hughes Incorporated；
IPC主号:

专利说明:

[0001] [001] The present invention relates, in general terms, to the management of fluid drilling equipment. More specifically, the present invention relates to systems, apparatus, program products and methods for ensuring the linearity of well-bottom drilling systems. Description of the Related Art
[0002] [002] An oil and gas reservoir is composed of porous and permeable rocks such as limestone, sandstone or clay, containing oil in its pores. The oil and gas stored in the reservoir are prevented from reaching the surface due to an impermeable rock, such as basalt, granite or shale. Oil and gas inside the reservoir can exert a substantial amount of vertical pressure on the impermeable rock.
[0003] [003] The parts of an oil and gas well can be extended through the non-permeable rock to access the oil and gas in the reservoir. The typical oil and gas well can also be thought of as a hole in the ground, in which a steel tube called a casing structure is placed. The annular space between the structure and the rock formation is filled with cement, ideally resulting in a smooth steel hole in the soil passing through the reservoir. The steel structure is generally fairly uniform and cylindrical in shape over most of the length of the structure, and even in areas where there is a significant horizontal fold, the steel structure is still quite uniform around the circumference. The "hole" formed by a drill bit does not always have such a cylindrical shape or circumference. This difference can cause deviations in the recently installed steel structure as it will tend to follow the contours of the drilling hole, at least to some extent. This drift in cylindrical terms (in circumference) can result in a deflection in the downhole pumping system assembly if it is brought into contact with any significant differences in structure; which can result in reduced life span failures and / or complete failure of the downhole pumping system assembly.
[0004] [004] In a process called completion, holes are generated in the structure at the depth of the reservoir allowing oil, gas and other fluids to enter the well, adding a smaller tube that is suspended from the surface well and which allows oil and gas to rise to the surface in a controlled manner.
[0005] [005] In a new well, the pressure in the reservoir is often sufficient for oil and gas to rise to the surface under its own pressure. Subsequently, when the pressure decreases, or in deeper wells, additional motivation is needed, such as that provided by a set of downhole pumping systems.
[0006] [006] As the oil and gas are removed, the pressure of oil and gas in the pores of the rock is reduced. This reduction in pressure results in an increase in the effective vertical deformation and the compaction of the reservoir. As the reservoir becomes compacted, very large forces are generated that deform the structure and the added hardware for completion. This deformation in the structure, whether caused by the removal of oil and gas, or by other means, can also result in a deflection in the pit-bottom pumping system assembly; which can result in reduced life span and / or complete failure of the downhole pumping system assembly.
[0007] [007] The removal of the downhole pumping system assembly or repair or replacement due to damage or premature failure caused by irregularities in the well structure can result in an interruption in the production of oil and gas wells, which can cost millions of dollars in lost revenue. As such, it is recognized by the inventors the need for systems and methods for the control and management / maintenance of the linearity of the downhole pumping system.
[0008] [008] Various technologies were examined to determine whether alternative technologies existed to try to solve the problem recognized by the inventors. No existing alternative technologies were found that were sufficiently effective. Childers et al., Down Hole Fiber Optic Real-Time Casing Monitor, Industrial and Commercial Applications of Smart Structures Technologies 2007, Proc. of SPIE vol. 6527, 65270J (2007), included here as a reference, describes an optical fiber application to perform well hole measurements used as part of a compaction and real-time monitoring (RTCM) project developed by the person responsible for the invention. Particularly. Childers et al. describe a Real Time Structure Imaging System (RTCI), used to directly measure the measurement compaction induced by the formation and damage of an oil and gas well structure. The RTCI System includes the surface instrumentation unit (SIU), a fixed inlet cable with standard cable clamps, and an RTCI cable connected to the surface of the structure or to the sand screen after drilling a well but before completion from the well. The input cable is fastened to the structure using line control clamps common in the industry. The fixing of the RTCI cable to the structure or to the sand sieve, however, must be rigid to allow efficient transfer of deformation and, therefore, typically be bonded with an industrial adhesive. In addition, the RTCI cable has a spiral or helical configuration to reduce the incidence of breakage by reducing the sensitivity to ring deformations. This setting, however, often results in a substantial reduction in sensitivity. Furthermore, once deployed, the RTCI cable cannot be easily repaired if there is a break or some other type of damage. Therefore, it is not expected that the RTCI system described in Childers et al. would provide sufficient sensitivity, durability or longevity with respect to determining or managing the linearity / alignment of a downhole pumping system set to a level capable of being provided by the modalities of the present invention.
[0009] [009] Also, for example, Smith, of US patent application No. 6,888,124 describes the use of a single fiber-optic cable incorporated with a series of electrical wires inside an electric motor stator to detect overheating and / or vibrations when the associated pump is blocked or dry or when a bearing is worn. Such a configuration, however, would not be expected to provide sufficient sensitivity to detect static deviations within the downhole pumping system assembly without substantial modification. In addition, since the cable is embedded with the electrical wires of the stator, even though the configuration can be modified to provide sufficient sensitivity to detect static deviations in the pump and / or motor of a downhole pumping system assembly, such a configuration would not be expected to allow the optical fiber to be promptly removed, adjusted, modified or repaired, and thus to offer the benefits provided by the modalities of the present invention. SUMMARY OF THE INVENTION
[0010] [010] In view of the foregoing, the modalities of the present invention advantageously provide systems and methods for managing the linearity of a downhole pumping system set that include submersible electric pumps (ESPs), progressive cavity pumps (PCPs) ) and electric submersible cavity pumps (ESPCPs), for example. Various embodiments of the present invention also advantageously provide for adjusting the position of the downhole pumping system assembly within a structure in order to position the downhole pumping system assembly to an ideal location within the structure of the well to reduce the deformation due to irregularities or deformations in the structure and to prolong the life of the pit-bottom pumping system.
[0011] [011] In its simplest form, an example of a system modality for monitoring the linearity of a downhole pumping system set during installation and selection of an ideal operating position for the pumping system set downhole inside the bore of the structure, includes a set of downhole pumping system connected to a distal end of a production pipeline line and configured to work inside the borehole hole to pump hydrocarbons through the production pipeline, an optical sensing fiber configured to reflect optical signals to provide signals that indicate axial deformation to the engine and / or the plurality of drilling phases of the downhole pumping system assembly, a deformation detection, for example, including discrete detection and optical interrogation components, etc., configured to transmit optical signals to for the optical sensing fiber and receiving optical signals reflected back from the optical sensing fiber to detect a deflection in one or more parts of the downhole pumping system assembly caused by a corresponding deflection in the well box, and optical, electrical and mechanical couplings to connect the optical detection fiber with the deformation detection unit. The downhole pumping system assembly includes a pump assembly and a motor assembly connected to a more distal part of the pump assembly by means of a coupling and / or to interface with a seal assembly, and / or a gas separator or other set.
[0012] [012] In accordance with an embodiment of the present invention, the optical sensing fiber is positioned inside a groove that extends longitudinally in at least parts of the external structure of the pump set of the pump set and within a groove that extends longitudinally in at least parts of the external structure of the motor assembly of the motor assembly. In an alternative embodiment of the present invention, a tube or other conduit containing the optical detection fiber can be positioned in the groove. In another alternative embodiment of the present invention, that tube or other conduit containing the optical detection fiber can be connected, directly or indirectly, to an external surface of the external structures of the pump and motor assemblies, for example, through the use of laser welding, etc., eliminating the need for one of the grooves on the outer surface of the external structures of the pump and motor assemblies.
[0013] [013] Deviations within the bore of the well structure adjacent to the well-bottom pumping system assembly during operation can cause an alignment deviation between one or more of the plurality of pump and motor phases. This misalignment or lack of linearity can result in reduced service life and premature failure of the downhole pumping system and / or engine assemblies; which can result in an interruption in production and a loss of revenue. Advantageously, the deformation detection unit may include software / firmware / programs adapted to detect and locate deflection areas within the bore of the structure to determine and / or allow the user to determine an ideal location for the pumping system assembly downhole inside the structure that minimizes fatigue in the downhole pumping system. BRIEF DESCRIPTION OF THE DRAWINGS
[0014] [014] So that the characteristics and advantages of the present invention, as well as others that will become evident, can be understood in more detail, a more particular description of the invention briefly summarized above can be taken as a reference of the modalities that are illustrated in the drawings annexes, and which form a part of this specification. It should be noted, however, that the drawings illustrate only different modalities of the invention and should therefore not be considered to limit the scope of the invention, since they include other equally effective modalities.
[0015] [015] FIG. 1 is an environmental view of a system for monitoring the linearity of a well-bottom pumping system set during installation and selection of an ideal operational position within the hole of a well structure according to one embodiment of the present invention ;
[0016] [016] FIG. 2A is a perspective view of the downhole pumping system assembly according to an embodiment of the present invention;
[0017] [017] FIG. 2B is a perspective view of the coupling sections of the coupling assembly of a downhole pumping system assembly according to an embodiment of the present invention;
[0018] [018] FIG. 3 is a cross-sectional view of the engine part of the downhole pumping system assembly of FIG. 2, taken along line 3-3 according to an embodiment of the present invention;
[0019] [019] FIG. 4 is a cross-sectional view of the outer structure of the motor assembly of the downhole pumping system assembly of FIG. 2 which has a multi-core optical fiber according to an embodiment of the present invention;
[0020] [020] FIG. 5 is a cross-sectional view of the external structure of the motor assembly of a well-bottom pumping system assembly similar to that of FIG. 3, but having multiple optical fibers and optical fiber grooves in accordance with an embodiment of the present invention;
[0021] [021] FIG. 6 is a cross-sectional view of the external structure of the motor assembly of a downhole pumping system assembly similar to that of FIG. 5, but each optical fiber being positioned within a conduit which is itself positioned in its respective optical fiber groove according to an embodiment of the present invention;
[0022] [022] FIG. 7 is a cross-sectional view of the external structure of the motor assembly of a downhole pumping system assembly similar to that of FIG. 5, but having multiple optical fibers within each optical fiber slot according to an embodiment of the present invention;
[0023] [023] FIG. 8 is a perspective view of an external structure of a downhole pumping system assembly according to an embodiment of the present invention;
[0024] [024] FIG. 9 is a cross-sectional view of the outer structure of the downhole pumping system assembly shown in FIG. 8, taken along line 9-9 according to an embodiment of the present invention; and
[0025] [025] FIG. 10 is a schematic block flow diagram of a method for monitoring the downhole pumping system set linearity during installation and selecting an ideal position for the downhole pumping system set accordingly. with an embodiment of the present invention. DETAILED DESCRIPTION
[0026] [026] The present invention will now be described in more detail below with reference to the accompanying drawings that illustrate embodiments of the invention. This invention can, however, be realized in many different ways and should not be interpreted as limited to the modalities illustrated here. Instead, these modalities are provided for this description to be thorough and complete, and will fully convey the scope of the invention to those skilled in the art. Similar numbers refer to similar elements. Prime notation, when used, indicates identical elements in alternative modalities.
[0027] [027] Optical fibers have become the communication medium of choice for long distance communication due to their excellent light transmission characteristics over long distances and the ability to manufacture these fibers in lengths of many kilometers. The light that is transmitted can also feed the sensors, thus obviating the need for long electrical wires. This is particularly important in the oil and gas industry, where chains of electronic sensors are used in wells to monitor hole conditions. An optical fiber chain inside a fiber optic system can be used to communicate information from the wells. drilling, as well as from wells already completed, to obtain various hole measurements. A series of low reflection fiber Bragg grids (FBGs) can be written on an optical fiber length, such as by photogravure, to provide hole measurements. In principle, the distribution of wavelengths of light reflected from an FBG is influenced by the temperature and the deformation state of the device, to which the FBG is rigidly attached. Therefore, optical fiber can be used to provide temperature, vibration, deformation and other measurements.
[0028] [028] Various methodologies can be used to obtain hole measurements, including, but not limited to, optical reflectometry in terms of time, coherence and frequency domains. Due to spatial resolution considerations, reflectometry in the optical frequency domain (OFDR), capable of spatial resolution in the order of 100 microns or more, is a technique that shows what is most promising in terms of application in oil wells and gas. In OFDR, the probe signal is generally an optical wave of continuously continuously scanned frequency, as from a tunable laser. The probe signal, which is ideally highly coherent, is scanned around a central frequency. The probe signal is divided and sent by two distinct optical pathways. The first path is relatively short and ends at a reference reflector at a known location. The second path is the length of the optical fiber containing the sensors. The reference reflector and sensors along the length of the optical fiber reflect the optical signals back to the signal source. These optical signals are converted into electrical signals by a photodetector. The signal from the reference reflector travels a shorter path, and a probe signal, generated at a particular frequency at a single point in time, is detected at different times than the reference reflector and the FBGs. A different frequency component resulting from the time delay in receiving the signal from the reference reflector and the FBGs in the optical fiber can be seen in the detector signal.
[0029] [029] As shown in FIGURES 1-10, various embodiments of the present invention employ and / or implement one or more of the technologies described above in a new and original way, in order to allow an operator to ensure that a set of downhole pumping 31 implant holes at the end of a production pipeline line 25, either installed or placed in an ideal location in a well 20, for example, ensuring alignment between the pumping phases (structure) and the structure of the wellhead pumping system assembly engine 31, which can be crucial for the life of the engine and the pumping phases of the wellhead pumping system assembly 31.
[0030] [030] In particular, FIG. 1 illustrates an environmental view of a production well (for example, an oil and gas well 20) that extends to a reservoir 21. The oil and gas well 20 includes a structure 23 implanted in a hole 22 drilled in reservoir 21 and a production line 25 which extends through an outlet of well 27 of well 20 and into hole 29 of structure 23. FIG. 1 also illustrates a system 30 for monitoring the linearity of a downhole pumping system set 31 during installation and selection of an ideal operating position for the downhole pumping system set 31 inside hole 29 of the structure 23, according to an exemplary embodiment of the present invention.
[0031] [031] The system 30, in its most basic form, includes a well-bottom pumping system set 31 connected to a more distal end of the production pipeline line 25 and configured to work inside the hole 29 of the structure 23 from well 20 to pump hydrocarbons through production pipeline 25. As additionally shown in FIGURES 2A-2B and 3, the wellhead pumping system set 31 includes a pump set 33 and a motor set 35 connected to a more distal part of the pump 33 together with several other components, including, for example, a gas separator 42 and a seal assembly / section 43. The motor assembly 35 includes a motor 36 with a rotor 44 and a stator 45 contained within an external structure of the motor assembly 47. The pump assembly 33 includes a plurality of longitudinally stacked pump phases 39 and an external structure of the pump assembly 41. A variable speed drive and / or u such components (not shown) that provide the energy or other motivating force to drive the motor 36, as is known and understood by those skilled in the art.
[0032] [032] In accordance with an embodiment of the present invention, the external structure of the pump assembly 41 has at least one longitudinally oriented groove 49 for receiving a portion of an optical sensing fiber 51. Similarly, the external structure of the assembly of motor 47 also includes at least one longitudinally oriented groove 49 ', also for receiving a portion of the optical sensing fiber 51.
[0033] [033] In this exemplary embodiment, the optical sensing fiber 51 is positioned within longitudinally oriented grooves 49 in the external structure of the pump assembly 41 and at least partially within the groove that extends longitudinally 49 'of the external structure of the pump assembly. motor 47 to receive and reflect optical signals to provide signals that indicate axial strain to motor assembly 35 and / or the plurality of pump stages 39 of pump 33 of the downhole pumping system assembly 31. As perhaps best illustrated in FIG. 2B, optical connectors 62, such as those known to those skilled in the art, can be used to connect optical sensing fiber 51 between various assemblies / sections 33, 35, 42, 43, etc., and a coupling or otherwise cover 37 to couple the sections / assemblies and / or protect the optical sensing fiber 51 and the optical connectors 62 that extend between them. Additionally and / or alternatively, a tube or half of a tube 48 can be used to form a bridge between the assemblies, such as, for example, the gas separator assembly 42 and the seal section assembly 43.
[0034] [034] Optical detection fiber 51 can be constructed to have a plurality of Bragg networks (not shown) and / or other reflection means to provide reflections of time-sparse or frequency-dependent light signals usable to measure the deformation applied in the pit-bottom pumping system set 31. Notes that measurements can be made using optical time domain reflectometric techniques, optical frequency domain reflectometric techniques, incoherent reflectometric techniques, along with other known to those skilled in the art, and may use a variety of detection platforms, including Raman backscatter, Brillouin diffusion, Rayleigh diffusion, or Bragg networks, along with others known to those skilled in the art.
[0035] [035] Referring again to FIG. 1, system 30 also includes a strain sensor, unit 53 configured to transmit optical signals to optical detection fiber 51 and to receive optical signals reflected back from optical detection fiber 51 to detect misalignment or other form of deflection 52 'in one or more parts of the downhole pumping system assembly 31 caused by a corresponding irregularity or other form of deflection 52 in the structure 23 of well 20, and also optical and electrical couplings (described later) to connect the optical detection fiber 51 with the deformation detection unit 53. If pre-existing due to imperfections in hole 22, or that occur later during operation, such as due to the compaction of the reservoir, deviations in hole 29 of structure 23 of well 30 adjacent to the wellhead pumping system assembly 31 may cause a shift in alignment between one or more of the plurality of pumping phases 39 and the motor assembly 35 or the components between them. This misalignment or lack of linearity can result in a shorter life span, and early failure of the downhole pumping system set 33 and / or the engine set 35; which can result in an interruption in production and loss of revenue. As such, in a preferred configuration, the deformation detection unit 53 may include software / firmware / programs or be configured to detect deflections in the downhole pumping system assembly 31; which proves the magnitude and location of deflection areas within hole 29 of structure 23, to determine and / or allow the user to determine can determine an ideal location for the downhole pumping system set 31 in the interior of structure 23 that minimizes fatigue in the pit-bottom pumping system set 31, caused by these deflections in structure 23.
[0036] [036] Referring again to FIGURES 2A and 3, according to the illustrated embodiment of the present invention, optical sensing fiber 51 is a single-core fiber rigidly attached to an inner surface of groove 49 on the outer surface of the outer structure of the pump assembly 41 and an internal surface of the groove 49 'on the external surface of the external structure of the motor assembly 47 to detect deformations applied to the downhole pumping system assembly 31 when implanted inside the hole 29 of the structure 23 of well 30. In addition, according to the exemplary configuration, the groove 49 on the external surface of the external structure of the pump assembly 41 and the groove 49 'on the external surface of the external structure of the motor assembly 47 is substantially filled with an epoxy 55, and this optical sensing fiber 51 is substantially and completely embedded within the groove 49 on the outer surface of the outer shell assembly mba 41 and inside the epoxy 55 positioned in the groove 49 'on the external surface of the external structure of the motor assembly 47. Note that other means known to those skilled in the art can be used to at least partially rigidly connect the detection fiber optics 51 to the internal surfaces of the slots 49, 49 '.
[0037] [037] As perhaps best illustrated in FIG. 4, in accordance with an alternative embodiment of the present invention, the optical detection fiber is, in the form of a multi-core optical detection fiber 51 ', positioned slidably (unbound or non-rigidly connected) directly on the inside the groove 49 and / or inside a conduit 54 (for example, SS, steel or plastic pipe) inside the groove 49 on the external surface of the external structure of the pump assembly 41 and directly inside the groove 49 'and / or inside a conduit 54 (for example, SS, steel or plastic pipe), welded or glued inside the groove 49 'on the outer surface of the outer frame of the motor assembly 47 to allow movement in it to stop so as to reduce the incidence of ruptures due to deformation that exceeds the strength of the optical detection fiber 51, 51 'potentially found by the well-bottom pumping system set 31, when implanted inside the hole 29 of the structure 23 of the well 20. I that is, the downhole pumping system assembly 31 may be subject to deformation; which would result in the rupture of the optical fiber 51, 51 ', if rigidly connected to the set 31. Consequently, in this configuration, the measurements made for each separate core 57 of the 51' fiber provide sufficient data in relation to the nuclear member or members 57 to , in essence, allow the optical fiber 51 'to provide sufficient data to the deformation detection unit 53 to determine the shape of the fiber 51' without a physical accessory of a rigid or semi-rigid component being deformed. That is, the curves in fiber 51 'can be determined by analyzing the light signals provided by the separate cores 57 which provide sufficient data to determine the strain differences between the cores 57. According to a preferred configuration, the analysis can be performed, for example, by the deformation detection unit 53 located on or near the surface.
[0038] [038] It is noted that, in this embodiment of the present invention, various means known to those skilled in the art can be used to fix the optical sensing fiber 51 'within the grooves 49, 49'. These include, but are not limited to, the use of a cover (not shown) placed on or inside the part of the external surface of the clamps of the external pump and motor structures (not shown) positioned inside the slots 49, 49 ' in a close relationship to the optical detection fiber 51 ', and the loop type fasteners (not shown), to name just a few. Furthermore, according to another embodiment of the present invention, conduit 54 can be laser welded or otherwise connected to an external surface of structures 41,47, negating the need for grooves 49, 49 '.
[0039] [039] FIG. 5 illustrates an alternative embodiment of the present invention, characterized in that the external surface of the external structure of the motor assembly 47 includes a plurality of grooves circumferentially spaced from each other 49 'that extend longitudinally along at least a substantial part of the external structure of the motor assembly 47, and in that the external surface of the external structure of the pump assembly 41 includes a plurality of corresponding circumferentially spaced slots 49 that extend longitudinally along at least a substantial part of the external structure of the pump assembly 41 to form a plurality of optical sensing fiber groove sets 49, 49 'to substantially contain a corresponding plurality of optical sensing fiber 51. It is noted that FIG. 6 illustrates a similar alternative embodiment of the present invention, but having each optical fiber 51 positioned inside a conduit 54, for example, using epoxy 55 ', which, in turn, is welded or epoxidized within the grooves 49, 49' , and FIG. 7 illustrates an alternative embodiment similar to the present invention, but which contains one or more multi-core fibers 51 'with multiple cores 57, instead of one or more corresponding to the single-core fibers 51. Other variations or combinations are found, however, within the scope of the present invention.
[0040] [040] FIGURES 8-9 illustrate another embodiment of the present invention, characterized by the external structure of the motor assembly 47 'and / or the external structure of the pump assembly and / or the external structure of the pump assembly and / or the external structure of one or more assemblies / sections of the downhole pumping system assembly include a helical shape of the 49 "groove. Other variations or combinations, including the use of ducts or tubes with various shapes and / or direct piping or connection of fibers to an external surface of structures 41, 45, are within the scope of the present invention.
[0041] [041] Referring again to FIG. 1, the system 30 may also include a well hole cable 61, for example, which extends through an outlet of the well 27 or the hole, and connected to an external surface of the production pipe 25 through a clamp such as, for example, a gun clamp 63 for transferring optical signals between the deformation detection unit 53 and the optical detection fiber or fibers 51, 51 '. System 30 also includes an opposite ferrite seal 65 and / or other type of mechanical and electrical connector connected to the well-hole cable 61 and optical sensing fiber or fibers 51, 51 'to provide an interface between the cable 61 and the fiber or fibers 51, 51 ', and a surface cable 67 that extends through the outlet of the well 27 and is connected to the well hole cable 61 and to the deformation detection unit 53 to transfer optical signals between the unit deformation detection 53 and well hole cable 61 and optical detection fibers 51, 51 '.
[0042] [042] The modalities of the present invention may include methods of managing the well-bottom pumping system assembly 31 during installation inside hole 29 of structure 23 of a hydrocarbon well such as well 20 positioned for extracting hydrocarbons from an underground reservoir, such as, for example, reservoir 21 (see, for example, FIG. 1). FIG. 10, for example, illustrates a flow diagram of an example of a method for monitoring the linearity of a downhole pumping system set 31 during installation and selecting an ideal position for the bottom pumping system set well 31 inside the hole 29 of the structure 23 of the well 20. According to the illustrated example, the method can include the installation steps of the well-bottom pumping system set 31 connected to the production line 25 of the hole 29 in structure 23 of well 20 (block 201), for detecting the linearity of the well-bottom pumping system set 31 during installation in a position below and adjacent to an initial operational target position for set 31 (block 203) , and adjusting the target operating position in response to the linearity determinations above and below the initial operating target position when the linearity detected in the initial operating target position is less than the linearity in any position directly above or below the initial operational target position (block 205).
[0043] [043] For example, suppose a pre-planed hole / depth location of 1000 feet. During installation of the downhole pumping system set 31 at a depth of about 1020 feet, the downhole pumping system set 31 undergoes a substantial deflection 52 'at a depth of 1000 feet and at a depth 1020 feet, probably caused by a corresponding irregularity 52 in structure 23 of well 20 (see, for example, FIG. 1). There was only a slight deflection 52 'at a depth of 1010 feet and no appreciable deviation 52' at a depth of 990 feet. Consequently, a depth of 990 feet or 1010 feet will be selected instead of the originally planned depth of 1000 feet. Note that in most cases, the position considered ideal based on the linearity readings will typically be expected to be between about 10 feet from the original target location, although greater positional selections are within the scope of the present invention.
[0044] [044] In addition, according to an alternative method modality, operators can run a set of non-functional downhole pumping systems or another form of simulator (not shown), for example, typically having dimensions and / or similar lengths of the external surface to first detect the conditions of the well-hole structure by means of the system described above 30 before installing the well-bottom pumping system set 31, to thereby beneficially reduce incidents of damage to the set of wells downhole pumping system 31 that may occur when there are deviations inside hole 29 of structure 23 of well 20 that may exceed the deformation capacities of the downhole pumping system assembly 31 during installation thereof.
[0045] [045] It is important to note that although the modalities of the present invention have been described in the context of a fully functional system, those skilled in the art will appreciate that the mechanism of at least parts of the present invention and / or its aspects are capable of being distributed in the form of computer-readable instructions in a variety of forms of execution on a processor, processors, or the like, and that the modalities of the present invention apply equally and regardless of the particular type of signal media used to actually carry out the distribution. Examples of computer-readable media include, but are not limited to: non-volatile media, encoded media such as ROMs, CD-ROMs and DVD-ROMs, or electrically programmable erasable memories (EEPROMs), recordable media such as floppy disks , hard drives, CD-R / RWs, DVD-RAMs, DVD-R / RWs, DVD + R / RWs, flash drives and other new types of memories, and transmission-type media such as digital and analog communication links. For example, such means may include operating instructions and operating instructions relating to the operation of the deformation detection unit 53 and the computer-implementable parts of the phases / operations of the method described above.
[0046] [046] Various embodiments of the present invention have several advantages. For example, several embodiments of the present invention allow an operator to ensure that an engine 35 and a pump 33 of a well-bottom pumping system assembly 31 are installed in an ideal position in a well 20 ensuring alignment between the structure of the phases of the pump 41 and the structure of the 47. The alignment and linearity of the pump 33 and the motor 35 can be crucial for the service life of the pump 33 and / or the motor 35. By connecting an optical fiber 51, 51 'to the along the length of the pump and motor structures 41, 47, any deviation in the linearity of the pump 33 and motor 35 can be detected, using, for example, strain measurements. Examples of measurement techniques that can be used to measure deformations include time domain and / or optical frequency domain reflectometric techniques, reflectometric techniques using Raman backscattering and / or the use of Bragg networks to detect deformations in the external structures 41, 47, and therefore also in the structure 23. The shape of the pump and motor structures 41, 47 can be determined using analysis techniques to interpret the measurements of deformations between structures 41, 47. Various modalities of the present invention also resort to detection methodologies in the form of optical fiber, such as, for example, the use of fibers of several cores 51 ', in which deformation differentials are used to infer local curves or globally, core fibers helical, as well as others.
[0047] [047] This application is a non-provisional and claims priority and for the benefit of US Provisional Patent Application No. 61/387, 060, filed on September 28, 2010, hereby incorporated by reference in its entirety.
[0048] [048] In the drawings and specification, a typical preferred embodiment of the invention has been described, and although specific terms are used, the terms are used in a descriptive sense and not for the purpose of limitation. The invention has been described in considerable detail with specific reference to these illustrated modalities. It will be evident, however, that various modifications and changes can be made within the spirit and scope of the invention, as described in the previous specification.

权利要求:
Claims (10)
[0001]
Method for monitoring the linearity of a well-bottom pumping system set (31) implanted inside a hole (29) of a well structure (23) positioned to extract hydrocarbons from an underground reservoir (21), in which the method comprises installing or lowering the well-bottom pumping system assembly (31) connected to a production pipe (25) in a hole (29) in a well structure (23) hydrocarbons (20), monitoring the linearity of a well-bottom pumping system set (31) to optimize the life of the well-bottom pumping system set (31), the method being characterized by the fact that it comprises the stage of: adjust the operational position of the downhole pumping system (31) in response to linearity determinations that exceed a limit value.
[0002]
Method according to claim 1, characterized by the fact that the step of monitoring the linearity of the downhole pumping system set (31) includes the monitoring of the linearity of the downhole pumping system set (31) during the operational implementation of the pit-bottom pumping system set (31).
[0003]
Method according to claim 1 or 2, characterized by the fact that the step of monitoring the linearity of the downhole pumping system set (31) includes monitoring the linearity of the downhole pumping system set ( 31) during prolonged operation of the downhole pumping system assembly (31).
[0004]
Method according to any one of claims 1 to 3, characterized in that the step of monitoring the linearity of the downhole pumping system set (31) includes detecting the linearity of the bottom pumping system set well (31) during the implementation of a position below and adjacent to an initial operational target position for the assembly (31).
[0005]
Method according to claim 4, characterized by the fact that it comprises the step of: adjust the target operating position in response to determinations of linearity above and below the initial operating target position when the linearity detected at the initial operating target position is less than the linearity at any position immediately above or immediately below the initial operating target position.
[0006]
Method of controlling the linearity of a well-bottom pumping system set (31) during installation inside a hole (29) of a well structure (23) positioned to extract hydrocarbons from a underground reservoir (21) and the selection of an optimum operational position for the well-bottom pumping system set (31) inside the hole (29) of the structure (23), the method comprising the installation of a set a well-bottom pumping system (31) connected to the production pipe (25) in a bore (29) in a structure (23) of a hydrocarbon well (20), the method being additionally characterized by the fact that which comprises the steps of: detecting the linearity of the downhole pumping system set (31) during installation to a position below and adjacent to an initial operational target position for the set; and adjust the target operating position in response to determinations of linearity above and below the initial operating target position when the linearity detected at the initial operating target position is less than the linearity at any position immediately above or immediately below the initial operating target position.
[0007]
Method according to claim 6, characterized in that the step of detecting the linearity of the downhole pumping system set (31) is performed by a substantially entire part of the installation below a wellhead outlet ( 27) to the well (20).
[0008]
Method according to claim 7, characterized in that the well-bottom pumping system set (31) is a non-functional well-bottom pumping system set (31) implanted to detect the structure conditions of wellheads before installing a functional wellhead pumping system set (31) to reduce the occurrence of damage to the functional wellhead pumping system set (31) that occurs when there are deviations (52) inside a hole (29) in the well structure (23) (20) that damage the functional well-bottom pumping system assembly (31) during its installation.
[0009]
Method according to claim 7, characterized by the fact that the well-bottom pumping system set (31) is a well-bottom pumping system set simulator (31) deployed to detect the conditions of the well structure downhole before installing a functional downhole pumping system assembly (31) to reduce the occurrence of damage to the functional downhole pumping system assembly (31) that occurs when there are deviations (52) in the inside a hole (29) of the well structure (23) that would damage the functional well-bottom pumping system assembly (31) during its installation.
[0010]
System (30) for monitoring the linearity of an electric submersible pump assembly (33) during installation inside a bore (29) of a structure (23) of a well (20) positioned to extract hydrocarbons from a underground reservoir (21) and select an optimum operating position for the electric submersible pump set (33) inside the bore (29) of the frame (23), the system (30) comprising an attached electric submersible pump set (33) at a distal end of a production tube line (25), the electric submersible pump assembly (33) including a pump (33) comprising a plurality of longitudinally stacked pump stages (39) and a motor (35, 36) connected to a more distal part of the pump (33) with a coupling (37) and configured to work inside the hole (29) of the structure (23) of the well (20) to pump hydrocarbons through the production pipe line (25 ), the system (30) being characterized by fact that: electric submersible pump assembly (33) where: the motor (35, 36) includes an external motor structure (47) with an external surface including a groove (49 ') which extends longitudinally along at least a substantial part of the external motor structure (47) and in parallel a longitudinal axis of the electric submersible pump assembly (33), the plurality of longitudinally stacked pump stages (39) is positioned within an external pump structure (41) with an external surface including a corresponding groove that extends longitudinally along at least a substantial part of the external pump structure (41) and parallel to the longitudinal axis of the electric submersible pump assembly (33), the groove (49 ') on the external surface of the external motor structure (47) is further positioned to align with the groove (49) on the external surface of the external pump structure (41); an optical sensing fiber (51.51 ') positioned within the longitudinally extending groove (49) of the pump's outer structure (41) and at least partially within the longitudinally extending groove (49') of the external structure of the motor (47), the optical sensing fiber (51, 51 ') configured to reflect the optical signals to provide signals that indicate the axial deformation of one or more of the following: the motor (35, 36) and one or more among the plurality of pump stages (39); a deformation detection unit (53) configured to transmit optical signals to the optical detection fiber (51, 51 ') and to receive the reflected optical signals back from inside the optical detection fiber (51, 51') to detecting a deformation of one or more parts of the electric submersible pump assembly (33) caused by a corresponding deflection in the structure (23) of the well (20), to thereby determine the optimal location for the electric submersible pump assembly (33) inside the hole (29) of the structure (23) that minimizes the electrical fatigue of the electric submersible pump assembly (33) resulting from an alignment deviation between one or more of the plurality of pump stages (39) and the motor (35, 36); a well-bottom cable (61) that extends through a wellhead outlet (27) and connected to an external surface of the production tube (25) to transfer optical signals between the deformation detection unit (53 ) and the optical detection fiber (51.51 '); an opposite seal (65) connected to the downhole cable (61) and the optical detection fiber (51, 51 ') to provide an interface between them; and a surface cable (67) that extends through the wellhead outlet (27) and connected to the wellhead cable (61) and the deformation detection unit (53) to transfer optical signals between the deformation detection (53) and optical detection fiber (51.51 ').

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同族专利:

公开号 | 公开日

GB2500497B|2018-04-11|

GB201801335D0|2018-03-14|

NO20130403A1|2013-04-24|

US9341054B2|2016-05-17|

WO2012047524A1|2012-04-12|

US20150129206A1|2015-05-14|

GB2500497A|2013-09-25|

GB201306888D0|2013-05-29|

GB2556261A|2018-05-23|

BR112013007142A2|2017-07-25|

US20120073804A1|2012-03-29|

US8950472B2|2015-02-10|

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法律状态:
2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

2019-08-06| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|

2020-02-04| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application [chapter 6.1 patent gazette]|

2020-04-22| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

2020-09-24| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 21/09/2011, OBSERVADAS AS CONDICOES LEGAIS. |

优先权:

申请号 | 申请日 | 专利标题

US38706010P| true| 2010-09-28|2010-09-28|

US61/387,060|2010-09-28|

US13/234,667|US8950472B2|2010-09-28|2011-09-16|System for monitoring linearity of down-hole pumping systems during deployment and related methods|

US13/234,667|2011-09-16|

PCT/US2011/052625|WO2012047524A1|2010-09-28|2011-09-21|System for monitoring linearity of down-hole pumping systems during deployment and realted methods|

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