Classifications

• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/14—Obtaining from a multiple-zone well
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B47/00—Survey of boreholes or wells
  • E21B47/06—Measuring temperature or pressure
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B47/00—Survey of boreholes or wells
  • E21B47/10—Locating fluid leaks, intrusions or movements
  • E21B47/113—Locating fluid leaks, intrusions or movements using electrical indications; using light radiations
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
  • E21B2200/02—Down-hole chokes or valves for variably regulating fluid flow

Definitions

• This disclosure relates generally to equipment utilized and operations performed in conjunction with subterranean wells and, in one example described below, more particularly provides a multiple zone integrated intelligent well completion.
• variable flow restricting device is
• an optical waveguide is positioned external to a completion string, and one or more pressure sensors sense pressure internal and/or external to the completion string.
• the system can include multiple well screens which filter fluid flowing between a completion string in the well and respective ones of the multiple zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the completion string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the multiple well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the multiple well screens.
• a completion string for use in a subterranean well is also described below.
• the completion string can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen. Also described below is a method of operating a completion string in a subterranean well.
• the method comprises: a) closing all of multiple flow control devices connected in the completion string, the completion string including multiple well screens which filter fluid flowing between the completion string and respective ones of multiple earth formation zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the completion string and at least one of the zones, the multiple flow control devices which variably restrict flow of the fluid through respective ones of the multiple well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the multiple well screens; b) at least partially opening a selected one of the flow control devices; and c) measuring a change in the property sensed by the optical waveguide and a change in the pressure of the fluid as a result of the opening of the selected one of the flow control devices.
• FIG. 1 is a representative partially cross-sectional view of a well system and associated method which can embody principles of this disclosure.
• FIGS. 2A-C are representative cross-sectional views of successive longitudinal sections of a completion string which may be used in the well system and method of FIG. 1, and which can embody principles of this disclosure.
• FIG. 3 is a representative cross-sectional view of a section of the completion string, with fluid flowing from an earth formation into the completion string.
• FIG. 4 is a representative elevational view of another section of the completion string.
• FIG. 5 is a representative cross-sectional view of another example of the well system and method.
• FIG. 6 is a representative cross-sectional view of a flow control device which may be used in the well system and method.
• FIG. 7 is a representative cross-sectional view of a wet connection which may be used in the well system and method.
• FIG. 8 is a representative cross-sectional view of an expansion joint which may be used in the well system and method.
• FIG. 1 Representatively illustrated in FIG. 1 is a well completion system 10 and associated method which can embody principles of this disclosure. However, it should be clearly understood that the system 10 and method are merely one example of an application of the principles of this disclosure.
• a completion string 12 has been installed in a wellbore 14 lined with casing 16 and cement 18.
• the wellbore 14 could be at least partially uncased or open hole.
• the completion string 12 includes multiple sets 20 of completion equipment. In some examples, all of the sets 20 of completion equipment can be conveyed into the well at the same time, and gravel 22 can be placed about well screens 24 included in the completion equipment, all in a single trip into the wellbore 14.
• Packers 26 are used to isolate multiple earth formation zones 28 from each other in the wellbore 14.
• the packers 26 seal off an annulus 30 formed radially between the
• each set 20 of completion equipment is a flow control device 32 and a hydraulic control device 34 which controls hydraulic actuation of the flow control device.
• a suitable flow control device which can variably restrict flow into or out of the completion string 12, is the infinitely variable interval control valve IV-ICV(TM) marketed by Halliburton Energy Services, Inc.
• a suitable hydraulic control device for controlling hydraulic actuation of the IV-ICV(TM) is the surface controlled reservoir analysis and management system, or SCRAMS(TM), which is also marketed by Halliburton Energy Services.
• a pressure sensor 36 is included for sensing pressure internal and/or external to the completion string 12.
• the pressure sensor 36 could be provided as part of the hydraulic control device 34 (such as, part of the SCRAMS(TM) device), or a separate pressure sensor may be used. If a separate pressure sensor 36 is used, a suitable sensor is the ROC(TM) pressure sensor marketed by Halliburton Energy Services, Inc.
• a gravel packing work string and service tool (not shown) used to convey the completion string 12 into the well is
• the production string 38 in this example includes seals 40 for sealingly engaging a seal bore 42 in an uppermost one of the packers 26, an expansion joint 44 for convenient spacing out to a tubing hanger in a wellhead (not shown), and a packer 46.
• the expansion joint 44 may be similar to a Long Space Out Travel Joint, or LSOTJ(TM), marketed by Halliburton Energy Services, Inc., except that provision is made for extending the lines 48 across the expansion joint.
• LSOTJ(TM) Long Space Out Travel Joint
• the seals 40 are stabbed into the seal bore 42, and then the expansion joint 44 is actuated to allow it to compress, so that proper spacing out is achieved for landing a wellhead above.
• the packer 46 is then set, for example, by applying pressure to one of the hydraulic lines 48.
• a wet connection is made between lines 48 carried on the production string and lines 50 carried on the completion string.
• the lines 48 , 50 each include one or more electrical, hydraulic and optical lines (e.g., at least one optical waveguide, such as, an optical fiber, optical ribbon, etc.).
• An example of such a wet connection is depicted in FIG. 7, and is described more fully below.
• the lines 48 , 50 are depicted as being external to the production string 38 and completion string 12 , respectively, but in other examples all or part of the lines could be positioned internal to the production and/or completion string, or in a wall of the production and/or completion string.
• the scope of this disclosure is not limited to any particular locations of the lines 48 , 50 .
• the optical waveguide(s) is/are external to the completion string 12 (for example, between the well screens 24 and the wellbore 14 ) , so that properties of fluid 52 which flows between the zones 28 and the interior of the completion string 12 can be readily detected by the optical waveguide ( s ) .
• the optical waveguide could be positioned in a wall of the casing 16 , external to the casing, in the cement 18 , etc.
• the optical waveguide is capable of sensing temperature and/or pressure of the fluid 52 .
• the optical waveguide may be part of a distributed
• DTS temperature sensing
• gratings and/or Brillouin backscattering in the optical waveguide could be detected as an indication of strain
• the fluid 52 is depicted in FIG. 1 as flowing from the zones 28 into the completion string 12, as in a production operation.
• the principles of this disclosure are also applicable to situations (such as, acidizing,
• all of the flow control devices 32 can be closed, to thereby prevent flow of the fluid 52 through all of the screens 24, and then one of the flow control devices can be opened to allow the fluid to flow through a corresponding one of the screens. In this manner, the properties of the fluid 52 which flows between the
• the pressure sensors 36 can meanwhile detect internal and/or external pressures longitudinally distributed along the completion string 12, and this will provide an operator with significant information on how and where the fluid 52 flows between the zones 28 and the interior of the completion string.
• This process can be repeated for each of the zones 28 and/or each of the sets 20 of completion equipment, so that the fluid 52 characteristics and flow paths can be
• FIGS. 2A-C an example of one longitudinal section of the completion string 12 is representatively illustrated. The illustrated section depicts how flow through the well screens 24 can be
• the section shown in FIGS. 2A-C may be used in the system 10 and completion string 12 of FIG. 1, or it may be used in other systems and/or completion strings.
• FIGS. 2A-C three of the flow control devices 32 are used to variably restrict flow through six of the well screens 24. This demonstrates that any number of flow control devices 32 and any number of well screens 24 may be used to control flow of the fluid 52 between a corresponding one of the zones 28 and the completion string 12. The scope of this disclosure is not limited to any particular number or combination of the various components of the completion string 12.
• Another flow control device 54 may be used to selectively permit and prevent substantially unrestricted flow through the well screens 24.
• a mechanically actuated sliding sleeve-type valve, etc. may be used to selectively permit and prevent substantially unrestricted flow through the well screens 24.
• the flow control device 54 can be closed to thereby prevent flow through the screens 24, so that sufficient pressure can be applied external to the screens to force fluid outward into the corresponding zone 28.
• An upper one of the hydraulic control devices 34 is used to control operation of an upper one of the flow control devices 32 (FIG. 2A) , and to control an intermediate one of the flow control devices (FIG. 2B) .
• a lower one of the hydraulic control devices 34 is used to control
• an inner tubular 60 is secured to an outer tubular 94 (for example, by means of threads, etc.), so that the inner tubular 60 can be used to support a weight of a remainder of the completion string 12 below.
• FIG. 3 an example of how the flow control device 32 can be used to control flow of the fluid 52 through the well screen 24 is representatively illustrated.
• the fluid 52 enters the well screen 24 and flows into an annular area 56 formed radially between a perforated base pipe 58 of the well screen and an inner tubular 60.
• the fluid 52 flows through the annular area 56 to the flow control device 32, which is contained within an outer tubular shroud 62.
• the flow control device 32 variably restricts the flow of the fluid 52 from the annular area 56 to a flow passage 64 extending longitudinally through the completion string 12. Such variable restriction may be used to balance
• variable restriction may be used to control a shape or extent of a water or steam flood front in the various zones, etc.
• FIG. 4 a manner in which the lines 50 may be routed through the completion string 12 is representatively illustrated.
• the shroud 62 is removed, so that the lines 50 extending from one of the flow control devices 32 (such as, the intermediate flow control device depicted in FIG. 2B) to a well screen 24 below the flow control device may be seen.
• the lines 50 extend from a connector 66 on the flow control device 32 to an end connection 68 of the well screen 24, wherein the lines are routed to another connector 70 for extending the lines further down the completion string 12.
• the end connection 68 may be provided with flow passages (not shown) to allow the fluid 52 to flow longitudinally through the end connection from the well screen 24 to the flow control device 32 via the annular area 56. Casting the end connection 68 can allow for forming complex flow passage and conduit shapes in the end connection, but other means of fabricating the end connection may be used, if desired.
• the set 20 of completion equipment includes only one each of the well screen 24, flow control device 32, hydraulic control device 34 and flow control device 54.
• the set 20 of completion equipment includes only one each of the well screen 24, flow control device 32, hydraulic control device 34 and flow control device 54.
• any number or combination of components may be used, in keeping with the scope of this disclosure.
• FIG. 5 example One difference in the FIG. 5 example is that the flow control device 54 and at least a portion of the flow control device 32 are positioned within the well screen 24. This can provide a more longitudinally compact configuration, and eliminate use of the shroud 62 . Thus, it will be appreciated that the scope of this disclosure is not limited to any particular configuration or arrangement of the components of the completion string 12 .
• hydraulic control device 34 can include the pressure sensor 36 , which can be ported to the interior flow passage 64 and/or to the annulus 30 external to the completion string 12 .
• Multiple pressure sensors 36 may be provided in the hydraulic control device 34 to separately sense pressures internal to, or external to, the completion string 12 .
• the hydraulic control device 34 includes electronics 72 (such as, one or more processors, memory, batteries, etc.) responsive to signals transmitted from a remote location (for example, a control station at the earth's surface, a sea floor installation, a floating rig, etc.) via the lines 50 to direct hydraulic pressure (via a hydraulic manifold, not shown) to an actuator 74 of the flow control device 32 .
• electronics 72 such as, one or more processors, memory, batteries, etc.
• the FIG. 6 flow control device 32 includes a sleeve 76 which is displaced by the actuator 74 relative to an opening 78 in an outer housing 80 , in order to variably restrict flow through the opening.
• the flow control device 32 also includes a position indicator 82 , so that the electronics 72 can verify whether the sleeve 76 is properly positioned to obtain a desired flow restriction.
• pressure sensor (s) 36 may be used to verify that a desired pressure differential is achieved across the flow control device 32 .
• a wet connection 84 can be made between the lines 48 on the production string 38 and the lines 50 on the completion string 12 is representatively illustrated.
• the wet connection 84 is made above the uppermost packer 26 , but in other examples the wet connection could be made within the packer, below the packer, or in another location.
• a wet connector 86 on the production string 38 is axially engaged with a wet connector 88 on the completion string 12 when the seals 40 are stabbed into the seal bore 42 .
• the wet connection 84 preferably includes connectors 86 , 88 for each of electrical, hydraulic and optical
• the lines 48 may be extended through the expansion joint 44 in the system 10 is representatively illustrated.
• the lines 48 preferably including electrical, hydraulic and optical lines
• the lines 48 are coiled between an inner mandrel 90 and an outer housing 92 of the expansion joint 44 .
• expansion joint 44 is not necessary in the system 10 .
• a spacing between the uppermost packer 26 and a tubing hanger seat in the wellhead (not shown) could be accurately measured, and the production string 38 could be configured correspondingly, in which case the packer 46 may not be used on the production string.
• flow control device 32 in the above examples is described as being a remotely hydraulically actuated variable choke, any type of flow control device which provides a variable resistance to flow may be used, in keeping with the scope of this disclosure.
• a remotely actuated inflow control device may be used.
• An inflow control device may be actuated using the hydraulic control device 34 described above, or relatively
• an autonomous inflow control device one which varies a resistance to flow without commands or actuation signals transmitted from a remote location
• an autonomous inflow control device such as those described in US Publication Nos. 2011/0042091, 2011/0297385, 2012/0048563 and others, may be used.
• an inflow control device (autonomous or remotely actuated) may be preferable for injection operations, for example, if precise regulation of flow resistance is not required.
• the scope of this disclosure is not limited to use of any particular type of flow control device, or use of a particular type of flow control device in a particular type of operation.
• a remotely operable sliding sleeve valve which opens on command from the surface could be utilized.
• An opening signal could be conveyed by electric control line, or the signal could be sent from the surface down the tubing, e.g., via HALSONICS (TM) pressure pulse telemetry, an ATS(TM) acoustic telemetry system, DYNALINK (TM) mud pulse telemetry system, an electromagnetic telemetry system, etc.
• the sliding sleeve valve could have a battery, a sensor, a computer (or at least a processor and memory), and an actuation system to open on command.
• separate pressure and/or temperature sensors may be conveyed into the completion string 12 during the method described above, in which characteristics and flow paths of the fluid 52 flowing between the completion string and the individual zones 28 are determined.
• a wireline or coiled tubing conveyed perforated dip tube could be conveyed into the completion string during or prior to performance of the method.
• a selectively variable flow control device 32 integrated with an optical sensor (e.g., an optical waveguide as part of the lines 50 ) external to the completion string 12 , and pressure sensors 36 ported to an interior and/or exterior of the completion string.
• an optical sensor e.g., an optical waveguide as part of the lines 50
• pressure sensors 36 ported to an interior and/or exterior of the completion string.
• the system 10 can include: multiple well screens 24 which filter fluid 52 flowing between a completion string 12 in the well and respective ones of the multiple zones 28 ; at least one optical waveguide 50 which senses at least one property of the fluid 52 as it flows between the completion string 12 and at least one of the zones 28 ; multiple flow control devices 32 which variably restrict flow of the fluid 52 through respective ones of the multiple well screens 24; and multiple pressure sensors 36 which sense pressure of the fluid 52 which flows through respective ones of the multiple well screens 24.
• the multiple well screens 24, the optical waveguide 50, the multiple flow control devices 32, and the multiple pressure sensors 36 can be installed in the well in a single trip into the well.
• the system 10 can also include multiple hydraulic control devices 34 which control application of hydraulic actuation pressure to respective ones of the multiple flow control devices 32.
• a single one of the hydraulic control devices 34 may control application of hydraulic actuation pressure to multiple ones of the flow control devices 32.
• the pressure sensors 36 may sense pressure of the fluid 52 external and/or internal to the completion string 12.
• the flow control devices 32 may comprise remotely hydraulically actuated variable chokes.
• the flow control devices 32 may comprise autonomous variable flow
• the flow control devices 32 receive the fluid 52 from the respective ones of the multiple well screens 24.
• the system 10 may include a combined hydraulic,
• the system 10 may include an expansion joint 44 with hydraulic, electrical and optical lines 48 traversing the expansion joint 44.
• the optical waveguide 50 can be positioned external to the well screens 24.
• the optical waveguide 50 can be
• the completion string 12 can include at least one well screen 24; at least one first flow control device 54; and at least one second flow control device 32, the second flow control device 32 being remotely operable.
• the first flow control device 54 selectively prevents and permits substantially unrestricted flow through the well screen 24.
• the second flow control device 32 variably restricts flow through the well screen 24.
• the completion string 12 can include a hydraulic control device 34 which controls application of hydraulic actuation pressure to the second flow control device 32.
• the second flow control device 32 may comprise multiple second flow control devices 32, and the hydraulic control device 34 may control application of hydraulic actuation pressure to the multiple second flow control devices 32.
• the completion string 12 can include at least one optical waveguide 50 which is operative to sense at least one property of a fluid 52 which flows through the well screen 24.
• the method can comprise: closing all of multiple flow control devices 32 connected in the completion string 12, the completion string 12 including multiple well screens 24 which filter fluid 52 flowing between the completion string 12 and respective ones of multiple earth formation zones 28, at least one optical waveguide 50 which senses at least one property of the fluid 52 as it flows between the completion string 12 and at least one of the zones 28, the multiple flow control devices 32 which variably restrict flow of the fluid 52 through respective ones of the multiple well screens 24, and multiple pressure sensors 36 which sense pressure of the fluid 52 which flows through respective ones of the multiple well screens 24; at least partially opening a first selected one of the flow control devices 32; and measuring a first change in the property sensed by the optical waveguide 50 and a first change in the pressure of the fluid 52 as a result of the opening of the first
• the method can also include: closing all of the
• multiple flow control devices 32 after the step of at least partially opening the first selected one of the flow control devices 32; at least partially opening a second selected one of the flow control devices 32; and measuring a second change in the property sensed by the optical waveguide 50 and a second change in the pressure of the fluid 52 as a result of the opening of the second selected one of the flow control devices 32.
• the method can include installing the multiple well screens 24, the optical waveguide 50, the multiple flow control devices 32, and the multiple pressure sensors 36 in the well in a single trip into the well.
• the method can include closing all of the flow control devices 32, thereby preventing inadvertent flow of the fluid 52 into the completion string 12. This step can be useful in a well control situation.
• the method can include closing all of the flow control devices 32, thereby preventing inadvertent flow of the fluid 52 out of the completion string 12. This step can be useful in preventing loss of the fluid 52 to the surrounding zones 28.
• structures disclosed as being separately formed can, in other examples, be integrally formed and vice versa.

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• Geology (AREA)
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• Mining & Mineral Resources (AREA)
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• General Life Sciences & Earth Sciences (AREA)
• Fluid Mechanics (AREA)
• Environmental & Geological Engineering (AREA)
• Geochemistry & Mineralogy (AREA)
• Geophysics (AREA)
• Earth Drilling (AREA)
• Light Guides In General And Applications Therefor (AREA)
• Special Spraying Apparatus (AREA)
• Fluid-Pressure Circuits (AREA)
• Bulkheads Adapted To Foundation Construction (AREA)
• Pipeline Systems (AREA)

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• 2012
  • 2012-09-26 SG SG11201502303UA patent/SG11201502303UA/en unknown
  • 2012-09-26 BR BR112015006645-3A patent/BR112015006645B1/pt active IP Right Grant
  • 2012-09-26 WO PCT/US2012/057215 patent/WO2014051557A1/en active Application Filing
  • 2012-09-26 MX MX2015003815A patent/MX355034B/es active IP Right Grant
  • 2012-09-26 EP EP19187957.6A patent/EP3578752B1/en active Active
  • 2012-09-26 AU AU2012391052A patent/AU2012391052B2/en active Active
  • 2012-09-26 EP EP12885563.2A patent/EP2900903B1/en active Active
  • 2012-09-26 BR BR122020004840-9A patent/BR122020004840B1/pt active IP Right Grant
• 2016
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