EP1880079A2 - Centreur sensible a la pression - Google Patents

Centreur sensible a la pression

Info

Publication number
EP1880079A2
EP1880079A2 EP06726895A EP06726895A EP1880079A2 EP 1880079 A2 EP1880079 A2 EP 1880079A2 EP 06726895 A EP06726895 A EP 06726895A EP 06726895 A EP06726895 A EP 06726895A EP 1880079 A2 EP1880079 A2 EP 1880079A2
Authority
EP
European Patent Office
Prior art keywords
structural component
hollow structural
centralizer
hollow
rupture
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.)
Withdrawn
Application number
EP06726895A
Other languages
German (de)
English (en)
Inventor
Ronald R. Faul
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.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services 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 Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Publication of EP1880079A2 publication Critical patent/EP1880079A2/fr
Withdrawn legal-status Critical Current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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/063—Valve or closure with destructible element, e.g. frangible disc
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1078—Stabilisers or centralisers for casing, tubing or drill pipes

Definitions

  • the present invention relates to systems and methods for controlling pressure in wellbores.
  • Annular pressure buildup within wellbores has been recognized in the oil and gas industry for many years as a serious problem. Fluids trapped in a wellbore or annular space in a wellbore will expand with a corresponding increase in temperature leading to a volume increase and increase in the force they exert upon the surrounding area. This pressure has been known to be a significant factor in the failure of subsea wells, including Well A-2 of British Petroleum 1999 Marlin development program in the deepwater program off the Gulf of Mexico. One relevant article is Practical and Successful Prevention of Annular Pressure Buildup on the Marlin Project. SPE International 77473, 2002, Richard F. Vargo, Jr., et al, and which is hereby incorporated by reference in its entirety.
  • Annular pressure buildup is the pressure generated by thermal expansion of trapped fluids as they are heated. When wellbore fluids heat up and expand in a closed system, the expansion causes high induced pressures. Most land and many offshore locations may be able to bleed this pressure through surface-accessible wellhead equipment. In subsea completions, the primary annulus between the tubing and production casing may be the only accessible annulus. Consequently, bleeding the outer annuli may not be possible. Therefore, when the risk of subsea APB exists, well designers should give serious consideration to appropriate mitigation as part of the fundamental well design.
  • Offshore hydrocarbon recovery operations are increasingly moving into deeper water and more remote locations.
  • Satellite wells are completed at the sea floor and are tied to remote platforms or other facilities through extended subsea pipelines.
  • Some of these pipelines extend through water that is thousands of feet deep, where temperatures of the water near the sea floor are in the range of about 40 0 F.
  • the hydrocarbon fluids usually produced along with some water, reach the sea floor at much higher temperatures, characteristic of depths thousands of feet below the sea floor.
  • APB In order for a well to experience APB, two conditions are generally known to be present. First, there must be a sealed region, typically an annulus, wherein pressure may build. Second, a temperature rise is generally associated with the increase in pressure.
  • a good starting point is to try to ensure that the annulus does not become trapped.
  • cement shortfall is usually designed. This assumes that cement heights will be below the previous casing shoe and that a trapped annulus condition may not occur.
  • cement can still channel because of poor mud displacement.
  • Such displacement problems are caused by poor casing eccentricity or poor credibility of the wellbore fluids during the primary cementing operation.
  • barite sag following drilling can cause a trapped condition.
  • a trapped condition can occur either by cementitious materials or due to the settling of weighting materials from the mud.
  • a second APB prevention technique consists of attaching syntactic crushable-foam wrap to the casing.
  • the syntactic foam contains small, hollow glass spheres filled with air at atmospheric pressure. When ABP reaches a certain level, the hollow spheres collapse. This collapse results in a correspondent increase in available volume to thereby decrease pressure. Data demonstrate that the volume required for an effective solution is about 2% to about 8% of the annular volume.
  • APB Another way of prevention of APB is the use of compressible fluids in the trapped annulus to absorb volume increases as the heat up occurs.
  • a final way of mitigating APB is by using enhanced casing products. Increased casing capacities can accommodate a higher degree of pressure buildup without detrimental effects to the casing or well. Extensive work has been applied here also involving advanced, probabilistic performance properties of the subject casings.
  • an innovative centralizer comprises a centralizing structure with at least one sealed hollow structural component where a rupture disk is capable of breaking in response to sufficient pressure.
  • the present innovations further teach a method of effecting a volumetric change in response to overpressure within a wellbore comprising at least one hollow structural component.
  • the present innovative systems and methods can be used to avoid production loss due to wellbore damage or the need to restrict hydrocarbon flow in an effort to keep production temperature below danger levels.
  • the centralizer can be fitted with a rupture component made part of the centralizer, screwed into the bottom of the centralizer by means of threads within the centralizer, or connected by some other means.
  • FIGS. Ia and Ib show a preferred embodiment of a centralizer.
  • FIG. 2 shows a preferred embodiment of a centralizer.
  • FIG. 3 shows a preferred embodiment of a centralizer configuration using a 'hinged' arrangement within a bore.
  • FIG. 4 shows a production system using a centralizer with hollow rupture components.
  • FIG. 5 shows a preferred embodiment of a centralizer with multiple rupture components.
  • FIG. 6 shows a preferred embodiment of a pressure responsive system with a centralizer and multiple rupture components.
  • FIG. 7 shows a preferred embodiment of a hollow rupture component.
  • FIG. 8 shows a preferred embodiment of a centralizer where an empty rupture component is affixed to the main chamber of the centralizer.
  • a centralizer is combined with a rupture disk to allow for the release of excess pressure from a wellbore.
  • the hollow components in this embodiment contain a burst disk or rupture disk, which are selected to rupture at a predetermined pressure as required by well hydrostatic pressure and other factors.
  • the inside and outside diameters of the centralizer preferably provide effective centering of the casing in the borehole or outer casing.
  • the number of struts and rupture and burst disks may be adjusted in such a way as to meet the specific pressure and volume needs of a specific project. For instance, in one embodiment, there may be six struts with one rupture disk in each strut. In another embodiment, there may be four struts with two rupture disks in each strut.
  • a centralizer is combined with a relief valve in order to allow for the release of excess pressure from a wellbore.
  • the hollow components in this embodiment contain a relief valve that is selected to open at a predetermined pressure as required by well hydrostatic pressure and other factors.
  • a relief valve is something that is not destroyed when it opens.
  • a hollow structural component is a prefabricated rigid structure capable of allowing for volumetric expansion.
  • the rupture disk is sealed in such a way as to 'burst' at a predetermined pressure to facilitate the production of hydrocarbons.
  • the centralizer may also comprise at least one centralizing structure and include at least one breakable structural component that can respond to pressure increase surges.
  • the breakable structural component can collapse, burst, or rupture to provide a volume change in response to overpressure.
  • One advantage of this embodiment is that pressures build up within boreholes can be alleviated.
  • Another advantage is that the volume in a well can be controlled in such a manner as to optimize the production within a well.
  • FIG. Ia shows a sample preferred embodiment of the centralizer unit 100. This is a side view of the centralizer unit itself, not showing the casing which, once the centralizer 100 has been installed, would normally pass through the axial central cavity 130.
  • the struts 110 of the centralizer 100 in this embodiment, run parallel with the wellbore 140.
  • One or more rupture disks are located in one or more of the struts. These struts are hollow structural components.
  • the centralizer is made of stainless steel. Carbon steel, chrome-moly, or titanium or other materials can be used instead.
  • FIG. Ib shows a sample preferred embodiment of one of the struts 110 of the centralizer unit 100.
  • This is a formed shape of tubular steel, having a hollow center (not visible in this figure).
  • a rupture disk 112 blocks the sole opening into the hollow center of strut 110. (Preferably a hole is drilled and tapped in the strut 110.)
  • the end of strut 110 is attached to circumferential element 120 by a weld 114, which also serves to close off the hollow within the strut 110.
  • the centralizer is made of stainless steel. Carbon steel, chrome-moly, or titanium or other materials can be used instead.
  • FIG. 2 shows a sample preferred embodiment of the pressure responsive system using centralizer unit 200.
  • This is a side view of the centralizer unit itself, not showing the casing which, once the centralizer 200 has been installed, would normally pass through the axial central cavity 230.
  • the struts 210 of the centralizer in this embodiment, run parallel with the wellbore 240.
  • One or more rupture disks are located in one or more of the struts.
  • the centralizer is made of stainless steel. Carbon steel, chrome-moly, or titanium or other materials can be used instead.
  • a centralizer is attached to the rupture component using threads 260.
  • FIG. 3 shows a sample preferred embodiment of the centralizer unit 300. This is a side view of the centralizer unit itself, not showing the casing which, once the centralizer 300 has been installed, would normally pass through the axial central cavity 330.
  • the struts 310 of the centralizer in this embodiment, run parallel with the wellbore 340.
  • One or more rupture disks are located in one or more of the struts.
  • the centralizer is made of stainless steel, but or course carbon steel or chrome-moly or titanium or other materials can be used instead.
  • a centralizer is attached to the rupture component using hinges 360.
  • FIG. 4 shows a production system 400 using a centralizer 410 with hollow rupture component 420 surrounded by wellbore 440.
  • a casing used to move the desired hydrocarbons or other material is illustrated by 470 in which hydrocarbons or other desired products may be moved from the well to some kind of recovery equipment located at 480.
  • FIG. 5 shows a centralizer system 500 with multiple rupture components 510, 520, and 530.
  • Rupture components 510, 520, and 530 are attached to the centralizer component 540.
  • Centralizer component 540 is attached to hollow struts 550.
  • Rupture components 510, 520, and 530 may be of different sizes and pressure sensitivities.
  • FIG. 6 shows a casing combination with centralizer and hollow rupture components.
  • a hollow component 600 contains multiple rupture components 610 and 630. Within said hollow component walls 640 a hole is drilled and the first rupture component is placed at 610. A second rupture component 630 is held in place by elements within the hollow component at 620.
  • FIG. 7 shows a hollow rupture component 700.
  • a ring 710 separates the sealed disc components 720 and 730.
  • Hinges '740 can attach hollow rupture component to the centralizer system.
  • Hollow rupture component can also be attached by means of threads found at 750.
  • FIG. 8 shows a centralizer system 800 with a rupture component 810 located at either end of the centralizer system 850 or 860. Additional rupture components may be placed at 820, 830, and 840. The structural centralizer support struts 850 are placed along the bore.
  • the present innovations are enabled as a downhole pressure adjusting system, comprising a centralizing structure and at least one closed hollow structural component wherein the hollow structural component is responsive to overpressure is claimed.
  • the present innovations are enabled as a downhole pressure adjusting system, comprising a structure for placement on a downhole casing wherein the structure includes at least one hollow structural component wherein the hollow structural component is sealed by means of one or more seals is also claimed.
  • the present innovations are enabled as a production system, comprising a casing and a centralizer which includes at least one hollow structural component is also claimed.
  • the pressure responsive system may be made out of any number of materials, including, but not limited to, stainless steel, carbon steel, titanium, or any number of other materials.
  • the number of struts, rupture disks, and relief valves may vary from embodiment to embodiment.
  • the downhole string may be in different forms, including, but not limited to a tubular string or casing string.
  • One variation includes replacing the rupture disks with relief valves or other structures that will allow the enclosed volume to open at a predetermined pressure.
  • a particular advantage of the hollow chamber (at atmospheric pressure or pressurized) to be transported to a downhole location with a rupture disk is that it can be designed to rupture at a predetermined stage of operations.
  • the hollow structural component may be physically part of the centralizer, or be attached thereto, or may be separate from the centralizer itself.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Safety Valves (AREA)

Abstract

L'invention concerne un centreur comprenant des éléments de structure creux. Dans au moins un mode de réalisation, l'élément de structure creux est fermé par une soupape ou par un disque de rupture. Lorsque des surpressions inacceptables surviennent, la soupape ou le disque de rupture se rompt pour permettre un afflux dans l'élément creux, ce qui enlève la pression et évite une détérioration éventuelle. Dans d'autres modes de réalisation, l'élément de structure creux s'affaisse pour augmenter le volume disponible.
EP06726895A 2005-04-27 2006-04-25 Centreur sensible a la pression Withdrawn EP1880079A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US11/116,003 US20060243435A1 (en) 2005-04-27 2005-04-27 Pressure responsive centralizer
PCT/GB2006/001506 WO2006114607A2 (fr) 2005-04-27 2006-04-25 Centreur sensible a la pression

Publications (1)

Publication Number Publication Date
EP1880079A2 true EP1880079A2 (fr) 2008-01-23

Family

ID=36636255

Family Applications (1)

Application Number Title Priority Date Filing Date
EP06726895A Withdrawn EP1880079A2 (fr) 2005-04-27 2006-04-25 Centreur sensible a la pression

Country Status (4)

Country Link
US (1) US20060243435A1 (fr)
EP (1) EP1880079A2 (fr)
MX (1) MX2007014979A (fr)
WO (1) WO2006114607A2 (fr)

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EP2350434A2 (fr) * 2008-10-31 2011-08-03 BP Corporation North America Inc. Particules creuses élastiques pour l'atténuation de l'accumulation d'une pression annulaire
US8066074B2 (en) * 2008-11-18 2011-11-29 Chevron U.S.A. Inc. Systems and methods for mitigating annular pressure buildup in an oil or gas well
CA2670218A1 (fr) * 2009-06-22 2010-12-22 Trican Well Service Ltd. Methode d'application de traitements de stimulation par disques de rupture
US20110155377A1 (en) * 2009-06-29 2011-06-30 Laun Lyle E Joint or coupling device incorporating a mechanically-induced weak point and method of use
US8082987B2 (en) * 2009-07-01 2011-12-27 Smith International, Inc. Hydraulically locking stabilizer
US8944167B2 (en) 2009-07-27 2015-02-03 Baker Hughes Incorporated Multi-zone fracturing completion
US8613321B2 (en) * 2009-07-27 2013-12-24 Baker Hughes Incorporated Bottom hole assembly with ported completion and methods of fracturing therewith
US8695716B2 (en) 2009-07-27 2014-04-15 Baker Hughes Incorporated Multi-zone fracturing completion
CN101994488A (zh) * 2009-08-25 2011-03-30 罗绍东 一种具有双向保护作用的螺杆泵井抽油杆扶正器
US8360151B2 (en) 2009-11-20 2013-01-29 Schlumberger Technology Corporation Methods for mitigation of annular pressure buildup in subterranean wells
GB201101566D0 (en) * 2011-01-31 2011-03-16 Tendeka Bv Downhole pressure relief apparatus
US9145753B2 (en) 2011-09-02 2015-09-29 Onesubsea Ip Uk Limited Trapped pressure compensator
US8931559B2 (en) * 2012-03-23 2015-01-13 Ncs Oilfield Services Canada, Inc. Downhole isolation and depressurization tool
US9057230B1 (en) 2014-03-19 2015-06-16 Ronald C. Parsons Expandable tubular with integral centralizers
US11123215B2 (en) 2016-08-16 2021-09-21 Renuka Pradhan Pressure relief apparatus for wound
WO2018170038A2 (fr) * 2017-03-14 2018-09-20 Antelope Oil Tool & Mfg. Co., Llc Chambre d'expansion

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Also Published As

Publication number Publication date
MX2007014979A (es) 2008-02-14
WO2006114607A3 (fr) 2007-05-10
WO2006114607A2 (fr) 2006-11-02
US20060243435A1 (en) 2006-11-02

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