WO2009114371A2 - Compensateur de pression pour des garnitures d’étanchéité actionnées de manière hydrostatique - Google Patents

Compensateur de pression pour des garnitures d’étanchéité actionnées de manière hydrostatique Download PDF

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Publication number
WO2009114371A2
WO2009114371A2 PCT/US2009/036108 US2009036108W WO2009114371A2 WO 2009114371 A2 WO2009114371 A2 WO 2009114371A2 US 2009036108 W US2009036108 W US 2009036108W WO 2009114371 A2 WO2009114371 A2 WO 2009114371A2
Authority
WO
WIPO (PCT)
Prior art keywords
setting
fluid
tool
chamber
pressure
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/US2009/036108
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English (en)
Other versions
WO2009114371A3 (fr
Inventor
James G. King
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Baker Hughes Holdings LLC
Original Assignee
Baker Hughes Inc
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 Baker Hughes Inc filed Critical Baker Hughes Inc
Publication of WO2009114371A2 publication Critical patent/WO2009114371A2/fr
Publication of WO2009114371A3 publication Critical patent/WO2009114371A3/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
    • E21B33/1295—Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure

Definitions

  • the invention relates generally to downhole tools, including packer devices.
  • the invention relates to methods of actuating downhole tools.
  • Some downhole tools use absolute well pressure activation to operate. They are also referred to as hydrostatically actuated tools.
  • absolute well pressure activation the absolute pressure in the wellbore is the sum of the hydrostatic pressure and any additional pressure generated from the surface of the well.
  • the tool to be actuated is constructed to hold atmospheric air pressure in an atmospheric o chamber. The tool is then run to depth. A rupture disc separates the atmospheric chamber from the wellbore fluid, which is under hydrostatic pressure. When the absolute pressure in the well exceeds the differential pressure rating of the rupture disc, the disc ruptures to permit fluid to enter the atmospheric chamber.
  • the pressurized well fluid entering the actuation chamber is applied to a setting piston to set the packer device 5 or otherwise actuate the downhole tool.
  • Tools which can be operated using absolute well pressure activation are described in, for example, U.S. Patent No. 6,779,600. SUMMARY OF THE INVENTION
  • the invention provides a design and method for operating downhole tools in response to absolute pressure.
  • a well packer device is provided with a packer element and slip elements which are set by axial compression.
  • the packer device has an actuation chamber which is in communication with a pressure compensator reservoir.
  • the actuation chamber has a fluid communication port which allows fluid communication between actuation chamber and the annulus surrounding the packer device.
  • the pressure compensator reservoir and actuation chamber are charged with a pressurized fluid, such as nitrogen.
  • the fluid pressure within the pressure compensator reservoir and actuation chamber is higher than atmospheric pressure.
  • the tool is actuated when the external wellbore pressure exceeds the burst pressure rating of the rupture disc plus the fluid pressure contained within the pressure compensator chamber and actuation chamber.
  • a setting piston is moved by the pressure of the fluid to set the packer device.
  • Pressure charging of the pressure compensator reservoir allows for the tool to be operated at greater depths and to remain operable under higher external pressures than possible if the actuation chamber was at atmospheric pressure.
  • Figures 1A, 1 B, 1C, 1 D and 1 E are a side, partial cross-sectional view of an exemplary packer device constructed in accordance with the present invention.
  • Figure 2 is a side, cross-sectional view of portions of an alternative packer device constructed in accordance with the present invention and in a run-in, unactuated position.
  • Figure 3 is a side, cross-sectiona! view of the packer device shown in Figure 2, now in an actuated position.
  • Figure 4 is a side, cross-sectional view of a further alternative device constructed i o in accordance with the present invention.
  • FIGS 1A, 1 B, 1C, 1 D and 1 E depict an exemplary packer device 10 constructed in accordance with the present invention.
  • the packer device 10 includes a central mandrel 12 having a threaded connection 14 at its upper axial end 16.
  • the central mandrel 12 is formed of an upper central mandrel portion 18, middle central mandrel portion 20, and lower central mandrel portion 22, and a lower sub 24, which are interconnected with one another by threaded connections, in a manner known in the art.
  • the lower sub 24 presents a lower threaded connection 26 at its lower axial end.
  • the threaded connections 14, 26 are used for interconnection of the packer device 10 into a0 wellbore production or injection string (not shown), as is known in the art.
  • the central mandrel 12 defines a central flowbore 28 along its length.
  • the packer device 10 generally features a debris barrier 30, a set of upper anchoring slips 32, an elastomeric packer assembly 34, and a set of lower anchoring slips 36.
  • the slip assemblies 32, 36 are set using axial compression of the assemblies with respect to the central mandrel 12 so as to cause the slip elements 38 of the slip assemblies 32, 36 to be urged radially outward, as is known in the art. As the construction and operation of such devices is well known, they will not be further described herein.
  • a setting collar 42 and body lock ring assembly 44 are located axially below the lower slip assembly 36.
  • the packer assembly 34 is set by axial compression as well so as to cause the elastomeric packer elements 40 to be extruded radially outward. Axial compression of the packer assembly 34 and slip assemblies 32, 36 is caused by upward axial movement of the setting collar 42 with respect to the central mandrel 12.
  • the lower portion of the packer device 10 includes a hydraulic setting section, generally shown at 46 and a hydrostatic setting assembly, generally shown at 48, which are used to generate the axial force to set the slip assemblies 32, 36 and the packer assembly 34.
  • the hydraulic backup setting piston 50 is moveably retained within a setting piston chamber 52 which is defined radially between the central mandrel 12 and an outer sleeve 54.
  • the backup setting piston 50 includes a compression end 56, which abuts the compression collar 42.
  • the piston 50 includes an enlarged sealing portion 58 with fluid seals 60 to provide fluid sealing against both the central mandrel 12 and the outer sleeve 54.
  • the enlarged portion 58 presents a fluid pressure receiving surface 62. It is noted that an upper setting piston chamber 52 is in fluid communication with the annulus 53 surrounding the tool 10 via a port 15 while a lower setting piston chamber 52' is in fluid communication with the flowbore 28 via a radial port 64 disposed through the central mandrel 12.
  • Pressurized fluid may enter the lower setting piston chamber 52' via the port 64 and be applied against the surface 62.
  • the backup setting piston may be used to set the packer assembly 34 and slip assemblies 32, 36.
  • the flowbore 28 is pressurized at the surface of the well to exude pressure upon the surface 62 of the backup setting piston 50.
  • the backup setting piston 50 is axially moved to cause the compression end 56 of the piston 50 to urge the setting collar 42 against the lower slip assembly 36.
  • pressurized fluid enters the lower chamber 52" through port 64, and the piston 50 moved, fluid is expelled from the upper chamber 52 into the annulus 53 through port 15. Setting force is retained in slips 32, 36 and packer 34 by body lock ring assembly 44.
  • the primary setting assembly 48 includes a setting sleeve 66 which is attached by one or more set screws 68 to the compression collar 42.
  • the lower end of the setting sleeve 66 is secured to outer sleeve 54.
  • a pressure chamber 55 is formed radially between the lower sleeve 72 and the central mandrel 12 (see Figure 1 D).
  • the chamber 55 is pressurized to a level above wellbore hydrostatic pressure.
  • the lower end of the outer sleeve 54 is secured by securing ring 70 to lower sleeve 72. Annular fluid seals 57 ensure pressure integrity of the pressure chamber 55.
  • a body lock ring assembly 74 of a type known in the art for ensuring one-way relative axial movement between components, is incorporated between the outer sleeve 54 and the central mandrel 12, as depicted in Figure 1 D.
  • the lower end of the lower sleeve 72 is affixed by a threaded connection 74 to an interlock assembly housing 76.
  • the interlock assembly housing 76 overlies the lower sub 24 without being affixed to it.
  • Seals 80 provide fluid sealing between the interlock assembly housing 76 and the lower sub 24.
  • a setting chamber 82 and an interlock assembly, generally indicated at 84, are retained radially between the interlock assembly housing 76 and the central mandrel 12.
  • the interlock assembly 84 includes a lock sleeve 86 that is moveably disposed within the setting chamber 82.
  • the lock sleeve 86 is affixed by shear pin 88 to an interlock piston 90.
  • the interlock piston 90 is secured by a locking dog 92 to the lower central mandrel portion 22.
  • a fluid pressure compensator reservoir 94 is defined within the lower sub 24.
  • the fluid pressure compensator reservoir 94 contains pressurized nitrogen.
  • a fluid communication passage 96 extends between the reservoir 94 and the setting chamber 82.
  • a fluid communication port 98 (see Fig. 1 E) is disposed through the interlock assembly housing 76 to permit fluid communication from the exterior annulus 100 into the setting chamber 82. The port 98 is initially closed off by a frangible rupture disc 102.
  • the reservoir 94 Prior to running the packer device into a wellbore, the reservoir 94 is filled with pressurized nitrogen or another pressurized fluid.
  • the reservoir 94 is pressurized to a pressure that is greater than atmospheric pressure.
  • the level of pressure within the reservoir 94 is set based upon the external wellbore pressure that the tool 10 is expected to be exposed to.
  • the reservoir 94 is pressurized to a level that approximates the expected exterior pressure. Therefore, the tool 10 may be actuated by increasing pressure within the annulus by an amount approximately equal to the burst rating of the rupture disc 102.
  • a fill port 104 is disposed through the exterior wall of the lower sub 24 to permit fluid to be communicated into the reservoir 94.
  • the fill port 104 is closed off with a removable plug.
  • the pressure within the reservoir 94 will be communicated to the setting chamber 82 via the passage 96.
  • One advantage of pressurizing the setting chamber 82 is that, at great depths, outer housing components, including the interlock assembly housing 76 will not be deformed or deflected radially inwardly, or very minimally so, by the significant hydrostatic wellbore pressure, so that the operational movement of members within the setting chamber 82 is not impeded by this deformation.
  • the fluid pressure compensator reservoir 94 is filled with pressurized fluid at the surface prior to running the tool 10 into a wellbore.
  • the packer device 10 is incorporated into a production tubing string in a manner known in the art. The production tubing string and packer device 10 are then disposed into a wellbore and lowered to a desired depth.
  • the annulus 100 is sufficiently pressurized at the surface of the wellbore so that the rupture disc 102 will burst and allow high pressure wellbore fluid to flow from the annulus 100 into the setting chamber 82.
  • the lock sleeve 86 urges the lock sleeve 86 axially upwardly within the chamber 82. Movement of the lock sleeve 86 causes shear member 88 to rupture and releases the locking dog 92 from engagement with the central mandrel 12. Once the locking dog 92 is released, the interlock assembly housing 76 and lower sleeve 72 are free to move axially with respect to the central mandrel 12.
  • the compression collar 64 is urged against the lower slip assembly 36 causing the slip assemblies 32, 36 i and the packer assembly 34 to be set.
  • the chamber 55 collapses.
  • Pressurization of the compensator reservoir 94 provides an increase in internal pressure for the setting chamber 82. This allows the packer device 10 to be run to deeper depths and resulting higher hydrostatic pressures before actuation occurs.
  • the amount of external fluid pressure required to destroy the rupture disc 102 is determined by adding the 5 internal pressure of the compensator reservoir 94 to the burst rating of the rupture disc 102.
  • FIG. 2 and 3 there is depicted an alternative packer assembly 200 wherein there is a single piston with balanced or nearly balanced atmospheric chambers which urge the piston up and down more or less equivalently.
  • the upper portions (not shown) of the packer assembly 200 may have the identical construction as the packer device 10 described previously.
  • the packer assembly 200 includes a central mandrel 202 and a bottom sub 204.
  • a setting cylinder 206 surrounds the central mandrel 202 above the bottom sub 204.
  • the setting cylinder 206 presents a radially-inwardly projecting piston 208 which contacts the outer radial surface 210 of the mandrel 202.
  • Q- ring seals 212 provide fluid sealing across the piston 208.
  • the setting cylinder 206 is initially affixed to the bottom sub 204 by frangible shear pins 214.
  • a first setting chamber, indicated generally at 216, is defined belowthe piston 208 and radially between the central mandrel 202 and the bottom sub 204. The lower end of the first setting chamber 216 is closed off by fluid seals 218.
  • a fluid port 220 is disposed through the lower sub 204 to provide fluid communication between the first setting chamber 216 and the surrounding annulus 222.
  • the port 22 is initially closed off by a frangible rupture disc 224.
  • a second setting chamber 226 is located above the piston 208 and defined radially between the setting cylinder 206 and the mandrel 202. The upper end of the second setting chamber 226 is closed off by a radial projection 228 from the central mandrel 202 and fluid seals 230. The second setting chamber 226 is in fluid communication with the first setting chamber 216 via a weep hole 232 or other restrictive fluid path, which is disposed through the piston 208.
  • a fluid pressure compensator reservoir 234 is defined within the bottom sub 204. The reservoir 234 is similar in structure and function to the fluid pressure compensator reservoir 94 described earlier. In a currently preferred embodiment, the fluid pressure compensator reservoir 234 contains pressurized nitrogen.
  • a fluid communication passage 236 extends between the reservoir 234 and the first setting chamber 216.
  • a chamber fill port 238 is preferably provided for readily filling the reservoir 234.
  • the reservoir 234 Prior to running the packer device 200 into a wellbore, the reservoir 234 is charged with fluid that is pressurized greater than atmospheric pressure, thereby enabling the packer assembly 200 to be run in deeper wells containing greater hydrostatic pressure.
  • the greater-than-atmospheric 5 pressure from the reservoir 234 is transmitted through the passage 236 to the first setting chamber 216 and through the weep hole 232 to the second setting chamber 226.
  • the annulus 222 is pressurized to rupture the rupture disc 224.
  • Fluid from the annulus 222 will pass through the port 220 and enter the first setting chamber 216.
  • the increased fluid pressure will bear against the lower side i o 238 of the piston 208 and cause the shear pins 214 to shear.
  • the setting cylinder 206 is released and moves upwardly with respect to the central mandrel 202.
  • the second setting chamber 226 is collapsed, and the setting cylinder 206 will set the associated packer and slip elements (not shown) in the manner described previously with regard to packer device 10.
  • FIG. 4 illustrates an exemplary alternative packer device 300 incorporating an improved setting assembly in accordance with the present invention.
  • the packer element 302 is located above the setting assembly 304 while a slip anchoring assembly 306 is located below the setting assembly 304.
  • the setting assembly 304 includes an upper setting cylinder 308 and a lower setting sleeve 310.
  • An upper 0 setting chamber 312 is defined radially between the central mandrel 314 and the upper setting cylinder 308.
  • the upper setting chamber 312 is bounded on its lower end by shoulder 316 and at its upper end by setting piston 318.
  • a charging port 320 is disposed through the setting cylinder 308 to permit the upper setting chamber 312 to be charged with a fluid.
  • the charging port 320 is closed off by a plug, as is known in the art.
  • a lower setting chamber 322 is defined radially between the central mandrel 314 and the lower setting sleeve 310.
  • the lower setting chamber 322 is bounded at its upper end by a fluid seal 324 between the lower setting sleeve 310 and the central mandrel 314.
  • the lower setting chamber 322 is bounded by a lower setting piston 326.
  • a fluid port 328 is disposed through the lower setting piston 310 to permit the lower setting chamber 322 to be charged with a fluid.
  • the fluid port 328 is closed off by a closure plug, as is known in the art.
  • a shear screw 330 secures the lower setting sleeve 326 to the upper setting sleeve 308.
  • the upper and lower setting chambers 312, 322 Prior to running the packer device 300 into a wellbore, the upper and lower setting chambers 312, 322 are charged with a fluid at a pressure that exceeds atmospheric pressure. This permits the packer device 300 to be run to deeper depths with higher hydrostatics within a wellbore.
  • the fluid pressure compensation reservoir is integrated into the setting chambers 312, 322.
  • the packer device 300 might also be constructed so as to have one or more separate fluid compensation reservoirs which is/are maintained separately from the setting chambers 312, 322.
  • the annulus surrounding the packer device 300 is pressurized from the surface to a predetermined level.
  • the increased fluid pressure acts upon the outer radial surfaces of the upper setting cylinder 308 and the lower setting sleeve 310 and particularly at the point 332 where the cylinder 308 and sleeve 310 meet and causes the shear screw 330 to rupture, thereby releasing the cylinder 308 from the sleeve 310.
  • the increased annular fluid pressure then causes the upper and

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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)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
  • Gripping On Spindles (AREA)

Abstract

La présente invention concerne des dispositifs et des procédés pour faire fonctionner un outil dans un puits de forage. Un outil de fond de trou comprend une partie fonctionnement d’outil comportant un élément d’outil mobile et une partie réglage comportant un piston de réglage et une chambre de réglage. Un réservoir de compensation de pression à fluide est en communication fluidique avec la chambre de réglage et contient un fluide sous pression qui décale la pression hydrostatique externe.
PCT/US2009/036108 2008-03-11 2009-03-05 Compensateur de pression pour des garnitures d’étanchéité actionnées de manière hydrostatique Ceased WO2009114371A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US12/046,168 2008-03-11
US12/046,168 US20090229832A1 (en) 2008-03-11 2008-03-11 Pressure Compensator for Hydrostatically-Actuated Packers

Publications (2)

Publication Number Publication Date
WO2009114371A2 true WO2009114371A2 (fr) 2009-09-17
WO2009114371A3 WO2009114371A3 (fr) 2009-12-03

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Country Status (2)

Country Link
US (1) US20090229832A1 (fr)
WO (1) WO2009114371A2 (fr)

Cited By (2)

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Publication number Priority date Publication date Assignee Title
CN105114027A (zh) * 2015-08-06 2015-12-02 东北石油大学 一种柔性自密封防肩突压缩式封隔器
CN115874975A (zh) * 2021-09-27 2023-03-31 大庆创革石油技术开发有限公司 重力坐封侧流封隔器

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US8453729B2 (en) * 2009-04-02 2013-06-04 Key Energy Services, Llc Hydraulic setting assembly
US8684096B2 (en) 2009-04-02 2014-04-01 Key Energy Services, Llc Anchor assembly and method of installing anchors
US9303477B2 (en) 2009-04-02 2016-04-05 Michael J. Harris Methods and apparatus for cementing wells
US8109339B2 (en) * 2009-08-21 2012-02-07 Baker Hughes Incorporated Zero backlash downhole setting tool and method
US9334338B2 (en) 2010-04-30 2016-05-10 Halliburton Energy Services, Inc. Water-soluble degradable synthetic vinyl polymers and related methods
US8347969B2 (en) * 2010-10-19 2013-01-08 Baker Hughes Incorporated Apparatus and method for compensating for pressure changes within an isolated annular space of a wellbore
US8813857B2 (en) 2011-02-17 2014-08-26 Baker Hughes Incorporated Annulus mounted potential energy driven setting tool
US8881798B2 (en) 2011-07-20 2014-11-11 Baker Hughes Incorporated Remote manipulation and control of subterranean tools
AU2012384526A1 (en) 2012-07-02 2015-01-22 Halliburton Energy Services, Inc. Packer assembly having dual hydrostatic pistons for redundant interventionless setting
US8983819B2 (en) * 2012-07-11 2015-03-17 Halliburton Energy Services, Inc. System, method and computer program product to simulate rupture disk and syntactic foam trapped annular pressure mitigation in downhole environments
US9009014B2 (en) * 2012-07-11 2015-04-14 Landmark Graphics Corporation System, method and computer program product to simulate the progressive failure of rupture disks in downhole environments
US9033056B2 (en) 2012-08-15 2015-05-19 Halliburton Energy Srvices, Inc. Pressure activated down hole systems and methods
US9238954B2 (en) 2012-08-15 2016-01-19 Halliburton Energy Services, Inc. Pressure activated down hole systems and methods
US9068413B2 (en) * 2012-09-14 2015-06-30 Baker Hughes Incorporated Multi-piston hydrostatic setting tool with locking feature and pressure balanced pistons
US9062506B2 (en) * 2012-09-14 2015-06-23 Baker Hughes Incorporated Multi-piston hydrostatic setting tool with locking feature outside actuation chambers for multiple pistons
US9068414B2 (en) * 2012-09-14 2015-06-30 Baker Hughes Incorporated Multi-piston hydrostatic setting tool with locking feature and a single lock for multiple pistons
US20150013965A1 (en) * 2013-06-24 2015-01-15 Blake Robin Cox Wellbore composite plug assembly
US9739118B2 (en) 2014-10-20 2017-08-22 Baker Hughes Incorporated Compensating pressure chamber for setting in low and high hydrostatic pressure applications
US9850725B2 (en) 2015-04-15 2017-12-26 Baker Hughes, A Ge Company, Llc One trip interventionless liner hanger and packer setting apparatus and method
US10190389B2 (en) 2016-11-18 2019-01-29 Baker Hughes, A Ge Company, Llc High pressure interventionless borehole tool setting force
EP3545164B1 (fr) 2018-02-02 2023-05-10 GeoDynamics, Inc. Outil de mise en place à actionnement hydraulique et procédé
US11248428B2 (en) * 2019-02-07 2022-02-15 Weatherford Technology Holdings, Llc Wellbore apparatus for setting a downhole tool
GB2595608B (en) * 2019-04-18 2022-11-30 Halliburton Energy Services Inc Anti-preset for packers
CN115506748A (zh) * 2022-09-26 2022-12-23 中海石油(中国)有限公司 封隔器坐封储能装置及其使用方法
WO2026076130A1 (fr) * 2024-10-01 2026-04-09 Schlumberger Technology Corporation Vanne de butée refermable à neutralisation mécanique

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Cited By (2)

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Publication number Priority date Publication date Assignee Title
CN105114027A (zh) * 2015-08-06 2015-12-02 东北石油大学 一种柔性自密封防肩突压缩式封隔器
CN115874975A (zh) * 2021-09-27 2023-03-31 大庆创革石油技术开发有限公司 重力坐封侧流封隔器

Also Published As

Publication number Publication date
US20090229832A1 (en) 2009-09-17
WO2009114371A3 (fr) 2009-12-03

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