WO2014082054A1 - Système de complétion, de stimulation et de production - Google Patents

Système de complétion, de stimulation et de production Download PDF

Info

Publication number
WO2014082054A1
WO2014082054A1 PCT/US2013/071817 US2013071817W WO2014082054A1 WO 2014082054 A1 WO2014082054 A1 WO 2014082054A1 US 2013071817 W US2013071817 W US 2013071817W WO 2014082054 A1 WO2014082054 A1 WO 2014082054A1
Authority
WO
WIPO (PCT)
Prior art keywords
sliding sleeve
check valve
control device
inflow control
tubular
Prior art date
Application number
PCT/US2013/071817
Other languages
English (en)
Inventor
Dinesh Patel
Original Assignee
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Holdings Limited
Schlumberger Technology B.V.
Prad Research And Development Limited
Schlumberger Technology Corporation
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Schlumberger Canada Limited, Services Petroliers Schlumberger, Schlumberger Holdings Limited, Schlumberger Technology B.V., Prad Research And Development Limited, Schlumberger Technology Corporation filed Critical Schlumberger Canada Limited
Publication of WO2014082054A1 publication Critical patent/WO2014082054A1/fr

Links

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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves

Definitions

  • Fig. 1 is a side sectional view of an interventionless zonally accessible completion system having injection valves and production inflow control devices (ICDs) in series.
  • ICDs production inflow control devices
  • FIG. 2 is a side sectional view of a completion system utilizing check valves with ICDs.
  • FIG. 3 is another embodiment of an interventionless zonally accessible completion system having a series of injection valves.
  • Fig. 4 is an enlarged view of an injection valve of Fig. 3 in a closed position.
  • FIG. 5 is an enlarged view of the injection valve of Fig. 4 with a ball disposed therein.
  • Fig. 6 is an enlarged view of the injection valve of Fig. 5 shifted to an open position via the ball.
  • Fig. 7 is an enlarged side view of an injection valve of Fig. 4 with a collapsible ball seat.
  • Fig. 8 is an enlarged side view of the valve of Fig. 7 receiving a ball with the seat in collapsed position.
  • Fig. 9 is an enlarged side view of the valve of Fig. 8 with the valve shifted to an open position and the seat in expanded position.
  • Fig. 10 is a side view of the embodiment of Fig. 4 with each valve shifted for production.
  • Fig. 1 1 is a side view of the embodiment of Fig. 9 with a valve shifted by running a shifting tool during a workover.
  • Embodiments described herein may take the form of multi-zonal stimulation and production completion systems. Some embodiments may take the form of a multi-zonal stimulation system implementing sliding sleeves. Embodiments may include inflow control devices (ICDs) that are part of a tubular positioned within a well and/or check valves integrated into the ICDs. The check valves and/or ICDs may be utilized, for example, at tubular regions outside of the sliding sleeves. In some embodiments, the check valves and ICDs may be incorporated into sleeve configurations as detailed herein. The ICDs may include apertures, valves and other features of a tubular that may control the flow of fluids and/or gas into or out of the tubular. The sliding sleeves may be actuated in any suitable manner. In some embodiments, the sliding sleeves may be actuated in an interventionless manner. That is, they may be actuated without intervention from a surface location.
  • ICDs inflow control devices
  • the sliding sleeves may be actuated in any suitable manner.
  • Embodiments of the present completion systems may include valves having one or more production ICDs, injection and production ICDs with check valves, a valve with a collapsible ball seat, a valve with a fixed ball seat and sliding sleeve, and/or combinations of one or more of these features.
  • Various embodiments of the completion systems are disclosed utilizing the above mentioned components. It should be appreciated that the example embodiments set forth herein are non-exhaustive.
  • the completion systems allow selective stimulation of individual segments or zones interventionlessly. The systems may aid in providing uniform production from each segment. The embodiments may also allow shutting off a water or gas producing zone.
  • a monitoring system such as a fiber optic monitoring system (e.g. DTS), or an electrical sensor or array of electric sensors may be deployed for monitoring reservoir parameters.
  • Fig. 1 depicts a completion system 100 disposed in a wellbore 102, according to one or more embodiments.
  • the wellbore 102 can be deviated, as shown, having a substantially vertical portion 104 and a substantially horizontal portion 108. Further, the wellbore 102 can include a casing 108. However, in some instances, the wellbore 102 or any portion(s) thereof can remain uncased.
  • the completion system 100 may include one or more zones (two are shown: 110, 112) having one or more completion segments 114, 115.
  • Production tubing 116 can extend in the wellbore 102 from the surface (not shown), down the vertical portion 104, and through one or more production packers 118.
  • the production packers can be any suitable type of mechanical and/or sweilable packer disposed in the vertical portion 104.
  • the production tubing 1 16 can be coupled to and/or extend at least partially through one or more of the zones 110, 112.
  • the production tubing 118 can be coupled to a completion first completion segment 114 and can be configured to be run into the wellbore 102 therewith.
  • Each of the production tubing 116, and the completion segments 114, 115 defines an inner bore 111 , 1 13, 117, respectively.
  • each inner bore 11 1 , 113, 117 can be in fluid communication with one another, allowing for fluid flow to or from the surface through the completion system 100.
  • the completion segments 114, 115 can each include a tubular body 103, 105 which defines the respective inner bore 113, 117.
  • the completion segments 114, 115 can each include one or more ICDs 128, 130, 132, 134, which may be configured to allow or prevent fluid flow out of the inner bore 113, 117.
  • the ICDs 128, 130, 132, 134 may be coupled to the tubular bodies 103, 105.
  • one or more of the ICDs 128, 130, 132, 134 can function as an injection ICD and one or more of the ICDs can function as a production ICD.
  • One or more of the ICDS 128, 130, 132, 134 can be opened by dropping a ball, dart, or other structure into the wellbore 102 and then subsequently closed and/or opened by a shifting tool or other type of actuating device conveyed on slick line, wireline, coiled tubing or pipe.
  • the ICDs 130, 134 may be opened by dropping a ball.
  • one or more of the ICDs 128, 130, 132, 134 can be remotely- actuated via electrical signal, hydraulic signal, fiber optic signals, wireless telemetry, combinations thereof, or the like, or can be mechanically-actuated by a shifting tool or actuating device conveyed on slick line, wireline, coiled tubing or, pipe.
  • the ICDs 128, 130, 132, 134 can each include one or more check valves or flow restrictors configured to allow fluid with a predetermined pressure differential to proceed one way through the valve, while substantially blocking fluid from reversing flow therethrough.
  • the ICDs 128, 130, 132, 134 can control the fluid flow into and out of the tubular bodies 103, 105 and the inner bores 113, 117 to allow for sequential treatment and/or production of the wellbore 102 proximal each of the completion zones 1 10, 112.
  • both production and injection ICDs can be included in a single completion segment 114, 115, each completion segment can be used in injection, flow back, and production operations, without removal and reconfiguration of the completion segments.
  • the completion segments 114,115 can also include one or more isolation packers 120 to isolate zones (e.g., to isolate zones 110, 112).
  • a control line 156 can extend along the production tubing 116 to the completion segments 114, 115, allowing topside, remote control of mechanical actuation of the ICDs 128, 130, 132, 134.
  • the control line 156 may take any suitable form including but not limited to fiber optic, electric, or hydraulic lines.
  • the ICDs 128, 132 are illustrated without check valves and ICDs 130, 134 include check valves 140, 142.
  • the check valves 140, 142 may take any suitable form and may be configured to allow one-way flow upon application of a threshold level of pressure.
  • the check valves 140, 142 may be configured to allow for fluid to flow out of the inner bores 113, 117 as part of a downhole operation, such as a stimulation or fracing operation.
  • the ICDs 130, 134 are configured as part of valves having sliding sleeves 144, 146 that may be actuated by a ball.
  • a ball For the sake of simplicity structures configured to be dropped into the wellbore 102 to open or close a valve, shift a sleeve, or otherwise perform an operation downhole will be referred to herein as a "ball,” with the understanding that as used herein a "ball” or “drop ball” can include a dart or any other structure deployed untethered into the well 102 or completion system 100 for the purposes of actuating a valve or performing a downhole operation.
  • a graduated ball system may be implemented where bail size progressively increases to actuate valves progressively from a distal end of the well 102 to a proximal end of the well (e.g., the end near the production packer 118).
  • the balls can have substantially the same diameter.
  • each valve can be actuated in sequence by dropping progressively larger balls through the production tubing or by dropping the same size balls therethrough.
  • some embodiments may include valves that can be mechanically-actuated flow control valves and ball-drop-actuated flow control valves.
  • one or more of the flow control valves 128, 130, 132,134 can be configured to receive a ball or dart for initial opening and, thereafter, can be actuated open or closed with other implements, such as mechanical engagement with a shifting tool and/or interventionless or remote actuation via hydraulics, electrical connection, or the like.
  • the balls for the ball-drop actuated flow control valves can be flowed back to surface during production.
  • the balls can be pulled out or milled for providing fluid or gas passage or the balls can be made from degradable or dissolvable materials that disintegrate over time.
  • the balls may dissolve when in contact with downhole materials such as various metals, calcium, magnesium, a combination thereof, various alloys disintegrated in water, or fluids, such as acid or water.
  • the rate at which the ball disintegrates can be controlled by selection and composition of the material out of which the ball is constructed and/or the composition and concentration of the disintegrating fluid or material.
  • the ICDs 130, 134 may be configured as injection valves and may be larger than the ICDs 128, 132. That is, a size of the aperture 148, 150 through which fluid may flow into or out of the inner bores 113, 117 may be larger in the ICDs 130, 134 than the ICDs 128, 132.
  • the ICDs 130, 134 will function as a primary or main ICD for the stimulation operation relative to the ICDs 128, 132. Due to the larger size of the apertures 148, 150, more fluid will pass through the ICDs 130, 134 than the other ICDs.
  • a ball 152 has shifted the sliding sleeve 146 in Fig. 1 opening the aperture 150 and allowing fluid flow (as indicated by the arrows).
  • the aperture 150 may serve as a primary or main injection point for the operation, while the other ICDs 132 may be secondary injection points, as they will allow lesser volume of fluid to pass therethrough.
  • the fluid With the check valves 140, 142 installed in the sliding sleeves 144, 146, the fluid may flow uni- directionally in some embodiments. That is, the fluid may flow out of the inner bores 113, 1 17 via the ICD 130, 134, when the valves are opened.
  • Fig. 2 depicts a completion system 200 similar to that of completion system 100 illustrated in Fig. 1 , however, the ICDs 128, 132 of completion segments 201 , 203 have check valves 202, 204. Where like features are depicted, the numbering has been carried forward from Fig. 1 .
  • the ICDs 130, 134 may take the form of dedicated injection ICDs and the ICDs 128, 132 may take the form of dedicated production ICDs. That is, ICDs 128, 132 may allow production of fluid from the formation therethrough but block stimulation fluid, for example, from exiting the completions segments.
  • the ICDs 130, 134 may allow for fluid to exit the inner bores 113, 117 of the completions segments and be injected into the formation while blocking production fluid from entering into the inner bores of the completion segments.
  • Fig. 3 depicts another embodiment of an interventionless zonally accessible completion system 300 having a series of injection valves.
  • the completion system 300 includes multiple completion segments 302, 304 each with multiple ICDs 306, 308, 310, 312. Each ICD 306, 308, 310,
  • each sliding sleeve 314, 316, 318, 320 may include a production check valve 322, 324, 328, 332, respectively, and an injection check valve 323, 326, 330, 324.
  • ICD 308 includes a sliding sleeve 316 with production check valve 324 and injection valve 326.
  • the production and injection check valves may have the same size. In other embodiments, the production and injection check valves may have different sizes. For example, the injection check valves may be larger than the production valves.
  • the production and injection valves may utilize a common aperture (e.g., aperture 340) or they may each have a separate aperture (not shown). Further, in some embodiments, the production check valves may have a different threshold actuation pressure than the injection check valves. For example, the production check valves may have a higher or lower threshold actuation pressure than the injection check valves.
  • the sliding sleeves may take different forms. Specifically, some sliding sleeves may include a collapsible ball seat while others may include a fixed ball seat.
  • Fig. 4 is an enlarged view of sliding sleeve 316 to better show certain features.
  • the fixed ball seat 350 is shown.
  • the fixed ball seat 350 may generally have an inner diameter 352 that is smaller than the outer diameter of the ball which it is intended to catch.
  • the seat 350 may be located at a downhole end of the sliding sleeve.
  • a plurality of seals 354 are also shown and may be provided to help prevent leakage of fluids through or around the sliding sleeve.
  • the sliding sleeve 316 may also include a profile 356 to receive a shifting tool.
  • an inner surface of the sliding sleeve 316 may have a recessed profile 356 that a shifting tool may engage to shift the sliding sleeve to an open or closed position.
  • a pressure equalization port 371 may be provided.
  • Fig. 5 shows a ball 360 landing on the fixed ball seat 350. Pressure may be applied to push the ball 360 and cause the ball to shift the sleeve 316 so that projection and injection ICDs may be aligned with aperture 362.
  • Fig. 6 shows the sleeve 316 shifted and stimulation fluid pushing through the injection check valve 326. Fig. 6 also illustrates the stimulation fluid being blocked by the check valve
  • Fig. 7 illustrates a collapsible ball seat 370, such as the collapsible ball seat of the ICD 306 and associated with the shifting sleeve 314.
  • the collapsible ball seat 370 may include collet fingers 372 that catch the ball 360 as shown in Fig. 8.
  • the collet fingers 372 may be positioned uphole from production and injection ICDs 380, 382 of the shifting sleeve. Once the sleeve 314 has shifted, the collet fingers 372 may expand radially into a recess 374 left by the shifted sleeve, as shown in Fig. 9.
  • the production and injection ICDs 380, 382 are aligned with aperture 383 and the check valves 384, 386 may be operational for injection and production operations.
  • the collet fingers 372 allow the ball to pass through the sliding sleeve 314.
  • the collapsible ball seat 370 allows for a single ball to actuate multiple sliding sleeve valves.
  • both of the sliding sleeves of the completion segment 302. It should be appreciated that in some embodiment the completion segments and/or zones may have more than one collapsible seat.
  • Fig. 10 illustrates the completion system 300 in a production mode with each of the shifting sleeves shifted to open the ICDs.
  • the balls may have been removed (e.g., through flowback or dissolving for example) and the production check valves 324, 382, 386, 388 allow for the fluid form the formation to flow from each zone into the tubing as indicated by the arrows.
  • Fig. 1 1 illustrates a valve shifting by running a tool 390 during workover.
  • the tool 390 may engage the sliding sleeve and then either move the sleeve up or down to open or close the ICD.
  • the tool may be run in hole once and used to shift multiple sleeves.
  • the tool 390 may be run on a tethering device 392, such as coiled tubing, wireline, slickline, pipe or in any other suitable manner.
  • Embodiments detailed hereinabove provide completion systems and techniques for attaining access, stimulation and production from isolated zones in an interventionless fashion.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Infusion, Injection, And Reservoir Apparatuses (AREA)

Abstract

Certains modes de réalisation de l'invention peuvent prendre la forme d'un système de complétion à utiliser dans un puits à zones multiples qui comprend un élément tubulaire disposé dans le puits. Des manchons coulissants peuvent être incorporés sur une base zone par zone comme faisant partie de l'élément tubulaire. Lesdits manchons peuvent être actionnés sans intervention et peuvent comprendre des clapets antiretour.
PCT/US2013/071817 2012-11-26 2013-11-26 Système de complétion, de stimulation et de production WO2014082054A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201261729741P 2012-11-26 2012-11-26
US61/729,741 2012-11-26

Publications (1)

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WO2014082054A1 true WO2014082054A1 (fr) 2014-05-30

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Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN106969406A (zh) * 2016-12-19 2017-07-21 陈俊年 一种取暖器倾倒关气阀
WO2019133320A1 (fr) * 2018-01-01 2019-07-04 Vertice Oil Tools Procédés et systèmes pour un manchon de fracturation
US10480286B2 (en) 2015-02-06 2019-11-19 Halliburton Energy Services, Inc. Multi-zone fracturing with full wellbore access
WO2021119852A1 (fr) 2019-12-20 2021-06-24 Ncs Multistage, Inc. Opérations de fracturation-à-fracturation asynchrones pour systèmes de récupération d'hydrocarbures et soupapes
US11767729B2 (en) 2020-07-08 2023-09-26 Saudi Arabian Oil Company Swellable packer for guiding an untethered device in a subterranean well

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6354378B1 (en) * 1998-11-18 2002-03-12 Schlumberger Technology Corporation Method and apparatus for formation isolation in a well
US20090211769A1 (en) * 2008-02-26 2009-08-27 Schlumberger Technology Corporation Apparatus and methods for setting one or more packers in a well bore
US20110073308A1 (en) * 2008-02-14 2011-03-31 Schlumberger Technology Corporation Valve apparatus for inflow control
US20110297393A1 (en) * 2010-05-26 2011-12-08 Schlumberger Technology Corporation Intelligent completion system for extended reach drilling wells
US20110303420A1 (en) * 2010-06-14 2011-12-15 Tage Thorkildsen Method and apparatus for use with an inflow control device

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6354378B1 (en) * 1998-11-18 2002-03-12 Schlumberger Technology Corporation Method and apparatus for formation isolation in a well
US20110073308A1 (en) * 2008-02-14 2011-03-31 Schlumberger Technology Corporation Valve apparatus for inflow control
US20090211769A1 (en) * 2008-02-26 2009-08-27 Schlumberger Technology Corporation Apparatus and methods for setting one or more packers in a well bore
US20110297393A1 (en) * 2010-05-26 2011-12-08 Schlumberger Technology Corporation Intelligent completion system for extended reach drilling wells
US20110303420A1 (en) * 2010-06-14 2011-12-15 Tage Thorkildsen Method and apparatus for use with an inflow control device

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10480286B2 (en) 2015-02-06 2019-11-19 Halliburton Energy Services, Inc. Multi-zone fracturing with full wellbore access
CN106969406A (zh) * 2016-12-19 2017-07-21 陈俊年 一种取暖器倾倒关气阀
WO2019133320A1 (fr) * 2018-01-01 2019-07-04 Vertice Oil Tools Procédés et systèmes pour un manchon de fracturation
US10662739B2 (en) 2018-01-01 2020-05-26 Vertice Oil Tools Methods and systems for a frac sleeve
WO2021119852A1 (fr) 2019-12-20 2021-06-24 Ncs Multistage, Inc. Opérations de fracturation-à-fracturation asynchrones pour systèmes de récupération d'hydrocarbures et soupapes
EP4077874A4 (fr) * 2019-12-20 2023-12-20 NCS Multistage Inc. Opérations de fracturation-à-fracturation asynchrones pour systèmes de récupération d'hydrocarbures et soupapes
US12104461B2 (en) 2019-12-20 2024-10-01 Ncs Multistage, Inc. Asynchronous frac-to-frac operations for hydrocarbon recovery and valve systems
US11767729B2 (en) 2020-07-08 2023-09-26 Saudi Arabian Oil Company Swellable packer for guiding an untethered device in a subterranean well

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