WO2010052502A1 - Procédé et appareil de communication pour les complétions avec insert - Google Patents

Procédé et appareil de communication pour les complétions avec insert Download PDF

Info

Publication number
WO2010052502A1
WO2010052502A1 PCT/GB2009/051492 GB2009051492W WO2010052502A1 WO 2010052502 A1 WO2010052502 A1 WO 2010052502A1 GB 2009051492 W GB2009051492 W GB 2009051492W WO 2010052502 A1 WO2010052502 A1 WO 2010052502A1
Authority
WO
WIPO (PCT)
Prior art keywords
communication
hanger
conduit
sub
tubing hanger
Prior art date
Application number
PCT/GB2009/051492
Other languages
English (en)
Inventor
Daniel Stewart
Roland Van Dort
Original Assignee
Caledyne 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 Caledyne Limited filed Critical Caledyne Limited
Priority to EP09752221A priority Critical patent/EP2356309A1/fr
Priority to GB1106703A priority patent/GB2476902A/en
Priority to US13/128,003 priority patent/US20110290507A1/en
Publication of WO2010052502A1 publication Critical patent/WO2010052502A1/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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser
    • E21B33/0385—Connectors used on well heads, e.g. for connecting blow-out preventer and riser electrical connectors
    • 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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • 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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • E21B33/047—Casing heads; Suspending casings or tubings in well heads for plural tubing strings
    • 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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells

Definitions

  • This invention relates to a method and apparatus for providing communication at surface for down-hole tools.
  • a work-over to install various items of new equipment. This can involve removing existing equipment, the cost of which may make the work-over uneconomic.
  • To overcome the cost of the work-over it is possible to install smaller diameter completion components inside the existing completion tubing string. As this work may be carried out at a lower cost than removing the existing equipment and tubing string, the economic case will be better. It is relatively easy to install this retrofit completion using standard techniques and practices. The purpose of installing this insert completion is to produce more oil and gas than was achieved with the existing equipment, either over a longer period to extend the field life or to produce oil or gas at higher rates.
  • This spool piece is used to provide the communication required from surface to the retrofit completion.
  • a spool piece either above or below the tree.
  • BOPs Blow Out Preventers
  • tubing hanger and tubing hanger bowl In standard wellheads, just below the Christmas tree, there is a tubing hanger and tubing hanger bowl. Within the tubing hanger is a landing nipple or threaded locater feature that allows for the installation of a tubing hanger plug.
  • the tubing hanger plug is installed to isolate the well so that the tree can be removed or modification work carried out in safety.
  • the well tubing string is suspended from the hanger in the bowl and locked down with a bolting system. This bolting system extends to the exterior of the wellhead to allow the tubing string to be removed.
  • the invention may utilise the tubing hanger plug (THP) landing profile and the bolting system if required to provide the communication path.
  • THP tubing hanger plug
  • the invention may remove one or more of the bolts and replaces it with a feed- through device, which connects to a device located in the THP landing nipple or in some other suitable location below the tree.
  • a new hole may be created to provide the access from the exterior to the well tubing string at the hanger, for example by hot-tapping which is an existing technique for creating new holes in pressurized equipment.
  • the design of the THP landing profile is such that the seal bore does not extend a sufficient distance above the locking groove to land seals to effect a seal tight communication between the feed-through and the internal insert hanger. It is desirable to allow installation of an insert completion hanger and communication sub that does not require annular seals on the hanger.
  • a method of providing a communication conduit for a down-hole tool comprising the steps of: forming a communication port at an existing portion of the down-hole tool located below the valves of the Christmas tree; and extending the communication conduit through the formed port.
  • the method may include forming the communication port at the tubing hanger.
  • the method may include forming the communication port at a bolt hole of the tubing hanger, and the step of forming the communication port may comprise removing an existing bolt of the tubing hanger.
  • the method may include installing a replacement fitting for the removed bolt.
  • the method may include forming a new aperture at the tubing hanger to form the communication port. The new aperture may be formed using hot-tapping.
  • the method may include the step of testing to ensure non-interference with an existing penetration.
  • the method may include providing a conduit hanger within the down-hole tool.
  • the conduit hanger may be mounted at an internal profile of the down-hole tool.
  • the conduit hanger may be mounted at an internal profile of the tubing hanger.
  • the conduit hanger may be mounted at the tubing hanger plug profile of the tubing hanger.
  • the method may include locking the conduit hanger in position using one or more keys.
  • the conduit hanger may include a profile for receiving a tubing hanger plug.
  • the method may include installing a communication sub within the down-hole tool.
  • the communication sub may be installed above the conduit hanger.
  • the method may include aligning the communication sub to the communication port.
  • the method may include sealing the communication port.
  • the replacement fitting may include sealing means, such as a sleeve.
  • the method may include injecting fluid to the communication conduit.
  • the method may include preventing injected fluid from exiting via the communication port.
  • the method may include providing one or more flow ports at the communication sub to allow fluid to pass through the communication sub.
  • a communication apparatus for a down-hole tool comprising: a communication port formed at an existing portion of the down-hole tool located below the valves of the Christmas tree; and a communication conduit extending through the communication port.
  • the communication port may be formed at the tubing hanger.
  • the communication port may be formed at a bolt hole of the tubing hanger.
  • the apparatus may include a replacement fitting for the removed bolt.
  • the apparatus may include a conduit hanger provided within the down-hole tool.
  • the conduit hanger may be adapted to be mounted at an internal profile of the down- hole tool.
  • the conduit hanger may be adapted to be mounted at an internal profile of the tubing hanger.
  • the conduit hanger may be adapted to be mounted at the tubing hanger plug profile of the tubing hanger.
  • the apparatus may include one or more keys for locking the conduit hanger in position.
  • the conduit hanger may include a profile for receiving a tubing hanger plug.
  • the apparatus may include a communication sub locatable within the down-hole tool.
  • the communication sub may be installable above the conduit hanger.
  • the replacement fitting may comprise alignment means, such as a pin, for aligning the communication sub to the communication port.
  • the communication sub may include alignment means, such as a slot, for aligning the communication sub to the communication port.
  • the replacement fitting may include sealing means, such as a sleeve, for sealing the communication port.
  • the communication sub may include one or more sub ports to allow the injection of fluid to the communication conduit.
  • a check valve may be provided at one or more of the sub ports to prevent injected fluid from exiting via the communication port.
  • the communication sub may include one or more flow ports to allow fluid to pass through the communication sub.
  • Figure 1 shows a solution for providing the communication path with a spool piece mounted above the Christmas tree, to demonstrate the current state of the art.
  • Figure 2 shows a solution for providing the communication path with a spool piece mounted below the Christmas tree to demonstrate the current state of the art.
  • Figure 3 shows a general view of the invention, with the position of the communication port at the tubing hanger .
  • Figure 4 shows a typical wellhead configuration with hold down bolts restraining a tubing hanger.
  • Figure 5 shows the same wellhead configuration with the new access port.
  • Figure 6 shows a detailed view of the conduit hanger in the THP landing nipple.
  • Figure 7 shows a detail of the orientation pin, part of the feedthrough system, used to orientate the communication sub.
  • Figure 8 shows the detail of the communication sub landed on top of the conduit hanger, orientated by the pin as shown in figure 7.
  • Figure 9 shows the feedthrough activated, providing communication from the exterior of the wellhead to the insert completion.
  • Figure 10 shows a cross-section of the communication sub with the feedthrough activated, showing the option of multiple ports within the communication sub.
  • Figure 11 shows the entire system installed within a typical tubing hanger system.
  • Figure 1 shows a schematic representation of a prior art wellhead valve block or Christmas tree 1, with a flowline 4 for production of oil and gas. Valves 5 are used to control the flow of oil and gas.
  • a spool piece 2A is positioned above the tree, with a conduit 6 running through the valves, effectively rendering them redundant.
  • the tree 1 is mounted on a tubing hanger 7, which has a profile 10 for positioning tubing hanger plugs or other items of equipment.
  • the prior art spool piece 2B is positioned below the tree, hence the existing flowline 4 no longer mates to the outlet from the tree 1. Valves 5 are free to operate.
  • Communication port 3 mates to a conduit hanger 8, locked into the spool piece 2B with keys 9.
  • Figures 1 and 2 expose the limitations to the current state of the art from both safety and economic aspects.
  • Figure 3 shows an alternative schematic according to the invention for connecting the conduit 6 of the insert completion via a new penetration 11 within the tubing hanger bowl, either through an existing threaded hole for the tie down bolts for the tubing hanger or an entirely new hole.
  • the valves 5 are free to operate and the flowline 4 is aligned to the outlet of the tree 1.
  • Figure 4 shows the tubing hanger held down by bolts 14. Preferably, one of these bolts is removed to perform the hot tapping operation to form the new port 11 as shown in Figure 5.
  • Existing penetrations 16 through the hanger 7 are commonplace, for installing hydraulic lines for operating down hole safety valves and for installing electrical lines for pressure and temperature gauges.
  • FIG. 6 shows that the conduit hanger 8 is locked into the tubing hanger profile 10 with keys 9.
  • the conduit 6 has a connector 13 within the conduit hanger 8.
  • the new port 11 is shown above the key groove 10 in the tubing hanger 7. However in certain instances the new port 11 may be below the key groove 10. This changes the internal detail of the conduit hanger 8, but not the overall principle of the invention.
  • a further profile 12 is included in the conduit hanger 8 to allow a tubing hanger plug to be installed within the conduit hanger 8. This allows the well to be isolated without removing the conduit 6 and conduit hanger 8.
  • the replacement fitting for the tie down bolt 14 is inserted into the bore of the tubing hanger 7 forming an alignment pin 17, as shown in Figure 7.
  • a further assembly 20 is installed above the conduit hanger 8 as shown in Figure 8. Assembly 20 contains a communication sub 18, in which is formed a j-slot, which interacts with the alignment pin 17 to align port 21 with the pin. Additionally, the sub 18 has axial float, to facilitate the alignment with the pin 17.
  • a sleeve 19A within the port fitting is moved to interact with the communication sub 18.
  • FIG. 10 shows that there may be one or more ports 21 within the communication sub 18. Within each port is a check valve 22, biased to allow injection of fluid from outside the wellhead to the conduit 6. The check valves 22 prevent injected fluid from leaving the open alignment ports. Flow ports 23 allow produced oil and gas to pass through the communication sub into the wellhead Christmas tree 1 as normal.
  • Figure 11 shows the installed system. It can be seen to those skilled in the art that various changes may be made to the features within this embodiment, without departing from the scope of the invention.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Branch Pipes, Bends, And The Like (AREA)
  • Valve Housings (AREA)
  • Electric Cable Installation (AREA)
  • Earth Drilling (AREA)

Abstract

La présente invention concerne un procédé visant à fournir une conduite de communication pour un outil de fond de trou, ledit procédé comprenant les étapes suivantes : formation d’un port de communication au niveau d’une partie existante de l’outil de fond de trou se trouvant sous les vannes de l’arbre de Noël ; et extension de la conduite de communication à travers ledit port ainsi formé.
PCT/GB2009/051492 2008-11-07 2009-11-06 Procédé et appareil de communication pour les complétions avec insert WO2010052502A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP09752221A EP2356309A1 (fr) 2008-11-07 2009-11-06 Procédé et appareil de communication pour les complétions avec insert
GB1106703A GB2476902A (en) 2008-11-07 2009-11-06 Communication method and apparatus for insert completions
US13/128,003 US20110290507A1 (en) 2008-11-07 2009-11-06 Communication Method and Apparatus for Insert Completions

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB0820407.5A GB0820407D0 (en) 2008-11-07 2008-11-07 Communication method and apparatus for insert completions
GB0820407.5 2008-11-07

Publications (1)

Publication Number Publication Date
WO2010052502A1 true WO2010052502A1 (fr) 2010-05-14

Family

ID=40139559

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2009/051492 WO2010052502A1 (fr) 2008-11-07 2009-11-06 Procédé et appareil de communication pour les complétions avec insert

Country Status (4)

Country Link
US (1) US20110290507A1 (fr)
EP (1) EP2356309A1 (fr)
GB (2) GB0820407D0 (fr)
WO (1) WO2010052502A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9163489B2 (en) 2009-03-13 2015-10-20 Bp Alternative Energy International Limited Fluid injection
WO2016118596A3 (fr) * 2015-01-20 2016-09-22 Ge Oil Gas Pressure Control Lp Conduite d'écoulement et té d'injection pour système de fracturation

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8403039B2 (en) * 2010-05-13 2013-03-26 Vetco Gray Inc. Tool and method for providing access to a wellhead annulus
US8479828B2 (en) * 2010-05-13 2013-07-09 Weatherford/Lamb, Inc. Wellhead control line deployment

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4972904A (en) * 1989-08-24 1990-11-27 Foster Oilfield Equipment Co. Geothermal well chemical injection system
WO2006133350A2 (fr) * 2005-06-08 2006-12-14 Bj Services Company, U.S.A. Procede et appareil de derivation de tete de puits
WO2008016663A2 (fr) * 2006-08-02 2008-02-07 Bj Services Company, U.S.A. Composants d'un arbre de Noël modifiÉ, et procÉDÉs associÉs pour l'utilisation d'un tubage hÉlicoïdal dans un puits
WO2008034024A2 (fr) * 2006-09-13 2008-03-20 Cameron International Corporation injecteur capillaire
WO2008089038A1 (fr) * 2007-01-12 2008-07-24 Bj Services Company Ensemble de tête de puits pour une colonne d'injection et son procédé
US20090294134A1 (en) * 2008-05-29 2009-12-03 Richard Jones Capillary hanger arrangement for deploying control line in existing wellhead

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6470971B1 (en) * 1999-11-15 2002-10-29 Abb Vetco Gray Inc. Tubing head control and pressure monitor device

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4972904A (en) * 1989-08-24 1990-11-27 Foster Oilfield Equipment Co. Geothermal well chemical injection system
WO2006133350A2 (fr) * 2005-06-08 2006-12-14 Bj Services Company, U.S.A. Procede et appareil de derivation de tete de puits
WO2008016663A2 (fr) * 2006-08-02 2008-02-07 Bj Services Company, U.S.A. Composants d'un arbre de Noël modifiÉ, et procÉDÉs associÉs pour l'utilisation d'un tubage hÉlicoïdal dans un puits
WO2008034024A2 (fr) * 2006-09-13 2008-03-20 Cameron International Corporation injecteur capillaire
WO2008089038A1 (fr) * 2007-01-12 2008-07-24 Bj Services Company Ensemble de tête de puits pour une colonne d'injection et son procédé
US20090294134A1 (en) * 2008-05-29 2009-12-03 Richard Jones Capillary hanger arrangement for deploying control line in existing wellhead

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9163489B2 (en) 2009-03-13 2015-10-20 Bp Alternative Energy International Limited Fluid injection
WO2016118596A3 (fr) * 2015-01-20 2016-09-22 Ge Oil Gas Pressure Control Lp Conduite d'écoulement et té d'injection pour système de fracturation

Also Published As

Publication number Publication date
GB201106703D0 (en) 2011-06-01
GB0820407D0 (en) 2008-12-17
GB2476902A (en) 2011-07-13
US20110290507A1 (en) 2011-12-01
EP2356309A1 (fr) 2011-08-17

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