WO2016024088A1 - Appareil et procédé de raccordement d'éléments tubulaires dans des puits de forage multi-latéraux - Google Patents

Appareil et procédé de raccordement d'éléments tubulaires dans des puits de forage multi-latéraux Download PDF

Info

Publication number
WO2016024088A1
WO2016024088A1 PCT/GB2015/052245 GB2015052245W WO2016024088A1 WO 2016024088 A1 WO2016024088 A1 WO 2016024088A1 GB 2015052245 W GB2015052245 W GB 2015052245W WO 2016024088 A1 WO2016024088 A1 WO 2016024088A1
Authority
WO
WIPO (PCT)
Prior art keywords
tubular
lateral
component
tubular member
wellbore
Prior art date
Application number
PCT/GB2015/052245
Other languages
English (en)
Inventor
David Glen Martin
Original Assignee
Meta Downhole Limited
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 Meta Downhole Limited filed Critical Meta Downhole Limited
Publication of WO2016024088A1 publication Critical patent/WO2016024088A1/fr
Priority to NO20170192A priority Critical patent/NO20170192A1/en

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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E21B43/106—Couplings or joints therefor
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
    • 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
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E21B43/108—Expandable screens or perforated liners
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes

Definitions

  • Oil and gas wells are completed by forming a borehole in the earth and then lining the borehole with a steel casing to form a wellbore.
  • a number of sections of casing are used.
  • a first section of casing is lowered into the wellbore and hung from the surface after the well has been drilled to a first designated depth.
  • Cement is then circulated in the annulus between the outer wall of the casing and the borehole.
  • the well is then drilled to a second designated depth and a second section of casing, having a smaller diameter, is run into the well.
  • the second section may either be "hung off" in a well head at a surface or is set at a depth such that the upper portion of the second section overlaps the lower portion of the first section casing.
  • the casing does not extend to the surface, then the casing is referred to as a liner.
  • the liner section is then fixed to the first section, such as by using a liner hanger.
  • the second casing section of liner is then cemented. This process is typically repeated with addition casing sections of increasing diameter until the well has been drilled to the total required depth.
  • the PBR has a smooth cylindrica l inner bore configured to receive the lower end of the tieback tubing wh ich is provided with seals on its outer d iameter to seal within the PBR when the two are brought into communication with one another.
  • seals on its outer d iameter to seal within the PBR when the two are brought into communication with one another.
  • thermal expansion and contraction of the liner, du ring which time the seals can move u p and down within the PBR leads to seal wear and u ltimately seal failure.
  • a method of connecting a first tubular member arrangement to a second tubular member located in a wellbore below a window to a wellbore lateral and to a third tubular member located in the wellbore lateral wherein the first tubular member is provided with a tubing diverter having a lateral tubular diverter component, and a lower end portion, the second tubular member includes an upper end portion which has a greater diameter than the diameter of the first tubular member lower end portion, and the third tubular member includes an upper end portion which has a greater diameter than the diameter of the lateral tubular diverter component, the method comprising :
  • the method may include providing the upper end portion of the second tubular member with a tieback component to which the first tubular member is resiliently connected. Provision of a tieback component at the second tubular member enables production from the wellbore to continue in conjunction with, or on an alternating basis, with any production from the lateral wellbore.
  • Each tubular member may be formed of a metal based material.
  • the use of metal based materials in each of the tubular members ensures that during the application of pressure to create the resilient seal, a metal to metal seal is formed.
  • the tubular member inserted into the lateral wellbore may be secured using a mechanism which also forms a wellbore formation zonal barrier.
  • a securing mechanism for example a hydraulically morphed tubular sleeve or the like will act both to secure the tubular member whilst providing a barrier between formation zones thus preventing cross contamination.
  • a lateral completion tubular component in the casing window; insert a first tubular member into the wellbore, the first tubular member being provided with a lower end portion having a diameter which is less than a bore diameter of the tieback component and a tubular diverter portion having a lateral tubular component with a diameter which is less than a bore diameter of the lateral completion component;
  • the method may include the step of applying internal fluid pressure to the tubing diverter to actuate the diverter to an operational status such that the lateral tubular diverter component is inserted into the lateral wellbore.
  • the lateral tubular diverter component may be a tubular member. The use of applying internal fluid pressure to the tubular diverter encourages a junction within the tubular diverter to open and encourages the diverter component to be directed into the lateral wellbore.
  • Each tubular component may be formed of a metal based material.
  • the use of metal base materials in each of the tubular members ensures that during the application of pressure to create the resilient seal, a metal to metal seal is formed.
  • Figure 1 shows a sectiona l side view of a wellbore arrangement of at least one step of an embodiment of the method of the present invention
  • Figure 2 shows a sectional side view of a wellbore and latera l wellbore arrangement of at least one step of an embodiment of the method of the present invention
  • Figures 3 - 7 each show a sectional side view of a wellbore and lateral wellbore arrangement indicating apparatus used in at least one step of an embod iment of the method of the present invention.
  • the method of the present invention relates to the provision of a formation and casing connection system for mu ltilateral wells.
  • a wellbore casing 12 is secured in a formation borehole 14 by cement 16.
  • the wellbore casing 12 leads to a surface (not shown) in the d irection generally indicated by arrow A.
  • a connection member, shown as a tieback receptacle 18, is secured within the casing 12 using a known method such as by use of a secu ring collar 20, wh ich secu res receptacle 18 to the internal surface 22 of the wall 23 of casing 12.
  • the tieback receptacle 18 is substantially cylind rical in form having a bore 19 therethroug h a nd upper opening 24 of receptacle 18 is of a first diameter.
  • the tieback receptacle 18 is of metal construction.
  • the internal su rface 26 of receptacle 18 is provided with metal protrusions 28 which annularly run arou nd the circumference of internal wall surface 26.
  • a lateral wellbore 30 is then provided, as is shown in Figure 2, at a location in the casing 12 above the tieback receptacle 18 by a casing window 32 being milled in the wall 23 of the casing 12 and into the formation 34.
  • the casing window milling technique used may be any generally known in the art.
  • the lateral borehole can then be completed as necessary either as an open hole or cased completion or with well treatment or prosecution production equipment being inserted with a lateral receptacle 38 being positioned with its upper opening 40 adjacent casing window 32 as is shown in Figure 3.
  • the lateral receptacle 38 is secured within the lateral using a known method for an uncased borehole arrangement, for example a sleeve arranged around a tubular insertion may be morphed hydraulically to conform with and provide a secure liner hanger as well as forming a secure zonal barrier in the lateral.
  • the lateral receptacle 38 is substantially cylindrical in form having a bore 39 therethrough and upper opening 40 of receptacle 38 is of a second diameter which may or may not be the same as the first diameter of receptacle 18.
  • the lateral receptacle 38 is of metal construction.
  • the internal surface 42 of receptacle 38 is provided with metal protrusions 44 which annularly run around the circumference of internal wall surface 42. Subsequently, an upper completion tubular 50, such as is shown in Figure 4, is lowered into casing 12.
  • Upper completion, tubular 50 is provided with a lateral tubular diverter component 52 having a lower completion tubing string 51 having a lower tubular portion 55, and a lateral wellbore tubing string 53 which has a lower end tubular portion 54.
  • a diverter component 52 is common in the art and may be referred to as a junction block or Y-block.
  • the lateral wellbore tubing 53 is formed of metal, has a substantially cylindrical form with a bore therethrough, and has lower end tubular portion 54 of a third diameter which is less than the second diameter of receptacle 38.
  • the lower completion tubing string 51 is similarly formed of metal, is substantially cylindrical in form having a bore therethrough and with a lower tubular portion 55 which is of a forth diameter which is less than the first diameter of receptacle 18.
  • the mechanism of the diverter component 52 has then fluid pressure, or morph pressure, applied by a tool (not shown) which causes the diverter mechanism to open, or latch advancing tubing strings 51 and 53.
  • the opening of the latch mechanism using fluid pressure causes the advancing of the lower end tubular portion 54 which is then encouraged, by way of the fluid pressure being applied to the diverter 52, to find and move into the lateral wellbore 30.
  • the fluid pressure may be applied in any suitable manner, for example by using a hydraulic tool (not shown), or by the application of fluid pressure at the surface of the wellbore (not shown).
  • the tool 60 is inserted into the tubular string 51 and receptacle 18 overlap within the bore of tubular string 51.
  • Elastomeric seals 62, 64 are arranged on the tool are then energised to that they expand radially outwardly and create a seal between the outer surface of the tool body and the inner surface bore of the tubular string 51.
  • a bounded chamber is thus created between the seals 62, 64 and hydraulic fluid is then pumped through the tool body so that it enters the chamber. Once the chamber is filled, continued pumping forces the outer surface of the tubular string end portion 55 to move radially outwards by the use of fluid pressure acting directly on the inner surface between the seals 62, 64.
  • Sufficient hydraulic fluid pressure is applied to cause the tubular member to morph itself around projections 28 onto the inner surface 26 of the receptacle 18.
  • the tubu lar string end 55 will undergo elastic expansion and continued expansion will cause the tubular string end 55 to undergo plastic deformation, conforming at least partially to the projections 28 and inner surface 26.
  • Sufficient pressure may be applied to also cause the receptacle 18 to undergo elastic deformation and expand by a small amount as contact is made. Pumping of the hydraulic fluid is then stopped. As the pressure is released the receptacle 18 returns to its original dimensions and creates a metal to metal seal against the deformed end 55 of tubular string 51. The tool 60 can then be removed from string 51.
  • the tool 60 can then be inserted into tubular string 53 as illustrated in Figure 7.
  • a known whipstock system 70 can be inserted into wellbore casing 12 and secured at the junction 52 to aid the location and orientation of the morph tool 60 into the tubular string 53.
  • a similar process as to that described with reference to Figure 6 is carried out to form a metal to metal seal between the deformed end 54 of string 53 and receptacle 38. This process ensures that a resilient metal to metal seal is formed at the lateral junction with wellbore 12 which is able to provide for vertical loading as well as resilience to thermally generated axial loads or hydraulic pressure during extraction.
  • a principle advantage of the present invention is that it provides a method which facilitates the simple formation, casing and connection of a lateral wellbore to an existing wellbore.
  • a further advantage of the present invention is that is provides a method of casing connection in a multilateral well which utilises a metal to metal seal between members without requiring a screw thread.
  • tubular members and receptacle units have been described as metal structures, however, only the end portions need to have metal construction to form the metal to metal seal required and thus the tubular members may be of composite form with metal ends.
  • whipstock systems, diverter joints and morph tools have been described, any suitable system may be substituted.

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)
  • Earth Drilling (AREA)
  • Mechanical Engineering (AREA)
  • Pressure Welding/Diffusion-Bonding (AREA)

Abstract

L'invention concerne un procédé de raccordement de tubage dans un puits multilatéral. Un composant tubulaire de raccord est placé dans un puits de forage au-dessous de la fenêtre de tubage. Un composant tubulaire d'achèvement latéral est installé dans la fenêtre de tubage. Des éléments tubulaires peuvent ensuite être placés dans le composant tubulaire de raccord et le composant d'achèvement latéral qui sont gonflés par pression interne pour former un joint d'étanchéité.
PCT/GB2015/052245 2014-08-12 2015-08-04 Appareil et procédé de raccordement d'éléments tubulaires dans des puits de forage multi-latéraux WO2016024088A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
NO20170192A NO20170192A1 (en) 2014-08-12 2017-02-08 Apparatus And Method Of Connecting Tubular Members In Multi-Lateral Wellbores

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB1414256.6 2014-08-12
GBGB1414256.6A GB201414256D0 (en) 2014-08-12 2014-08-12 Apparatus and method of connecting tubular members in multi-lateral wellbores

Publications (1)

Publication Number Publication Date
WO2016024088A1 true WO2016024088A1 (fr) 2016-02-18

Family

ID=51629640

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2015/052245 WO2016024088A1 (fr) 2014-08-12 2015-08-04 Appareil et procédé de raccordement d'éléments tubulaires dans des puits de forage multi-latéraux

Country Status (4)

Country Link
US (1) US20160047176A1 (fr)
GB (2) GB201414256D0 (fr)
NO (1) NO20170192A1 (fr)
WO (1) WO2016024088A1 (fr)

Cited By (1)

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WO2022261056A1 (fr) * 2021-06-07 2022-12-15 Halliburton Energy Services, Inc. Système de fracturation multilatéral 10.000-psi à grands diamètres internes pour un marché non classique

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US8904617B2 (en) * 2010-03-23 2014-12-09 Baker Hughes Incorporated Diverting system and method of running a tubular
GB2512506B (en) 2014-05-02 2015-07-08 Meta Downhole Ltd Morphable anchor
US11873691B2 (en) 2019-06-14 2024-01-16 Schlumberger Technology Corporation Load anchor with sealing
WO2021158519A1 (fr) * 2020-02-03 2021-08-12 Schlumberger Technology Corporation Méthodologie et système de complétion intelligente et multilatérale de puits
CA3237335A1 (fr) * 2021-11-04 2023-05-11 Schlumberger Canada Limited Systemes et procedes pour des completions multilaterales

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Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2398132A (en) 2002-02-22 2004-08-11 Sumitomo Metal Mining Co Optical fiber feed-through
US20040168808A1 (en) * 2002-03-21 2004-09-02 Smith Ray C. Monobore wellbore and method for completing same
US20050000697A1 (en) * 2002-07-06 2005-01-06 Abercrombie Simpson Neil Andrew Formed tubulars
GB2398312A (en) 2003-02-13 2004-08-18 Read Well Services Ltd Downhole tubular sealing apparatus
GB2474692A (en) 2009-10-23 2011-04-27 Read Well Services Ltd A method for connecting tubular members in a wellbore
US20140000911A1 (en) * 2012-07-02 2014-01-02 Andrew John Joseph Gorrara Apparatus and Method for Use In Slim Hole Wells
US20140090894A1 (en) * 2012-09-28 2014-04-03 John Chysostom Wolf Diverter latch assembly system

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2022261056A1 (fr) * 2021-06-07 2022-12-15 Halliburton Energy Services, Inc. Système de fracturation multilatéral 10.000-psi à grands diamètres internes pour un marché non classique
GB2619892A (en) * 2021-06-07 2023-12-20 Halliburton Energy Services Inc 10,000-Psi multilateral fracking system with large internal diameters for unconventional market

Also Published As

Publication number Publication date
NO20170192A1 (en) 2017-02-08
GB201513757D0 (en) 2015-09-16
GB2531399A (en) 2016-04-20
GB2531399B (en) 2017-07-26
GB201414256D0 (en) 2014-09-24
US20160047176A1 (en) 2016-02-18

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