WO2018222732A1 - Procédé de forage et de complétion d'un puits - Google Patents

Procédé de forage et de complétion d'un puits Download PDF

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Publication number
WO2018222732A1
WO2018222732A1 PCT/US2018/035158 US2018035158W WO2018222732A1 WO 2018222732 A1 WO2018222732 A1 WO 2018222732A1 US 2018035158 W US2018035158 W US 2018035158W WO 2018222732 A1 WO2018222732 A1 WO 2018222732A1
Authority
WO
WIPO (PCT)
Prior art keywords
bop stack
riser
high pressure
psi
well
Prior art date
Application number
PCT/US2018/035158
Other languages
English (en)
Inventor
James V. Maher
Original Assignee
Maher James V
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 Maher James V filed Critical Maher James V
Priority to BR112019025337-8A priority Critical patent/BR112019025337B1/pt
Publication of WO2018222732A1 publication Critical patent/WO2018222732A1/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
    • E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
    • E21B33/064—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers specially adapted for underwater 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • 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
    • 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
    • E21B33/043—Casing heads; Suspending casings or tubings in well heads specially adapted for underwater 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
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • E21B33/076—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations

Definitions

  • This disclosure relates generally to methods for drilling and completing subsea hydrocarbon wells.
  • the disclosure describes a method for completing a well.
  • the method may comprise the step of removing a conventional blowout preventer (BOP) stack from the subsea wellhead after construction of a wellbore below the subsea wellhead.
  • the method may further comprise the step of coupling a surface BOP stack to the subsea wellhead via a high pressure riser.
  • the method may further comprise the step of completing the well through the surface BOP stack.
  • the method may further comprise the step of coupling a mudline closure device between the subsea wellhead and the high pressure riser.
  • the disclosure describes a method for workover or intervention operations with a well.
  • the method may comprise the step of coupling a surface BOP stack to a subsea tree via a high pressure riser.
  • the method may further comprise the step of performing the workover or intervention operations through the surface BOP stack.
  • the method may further comprise the step of coupling a mudline closure device between the subsea wellhead and the high pressure riser.
  • the disclosure describes a method a method for constructing and completing a well.
  • the method may comprise the step of coupling a conventional BOP stack to a subsea wellhead via a conventional riser.
  • the method may further comprise the step of drilling a wellbore through the conventional BOP stack and conventional riser.
  • the method may further comprise the step of casing the wellbore through the conventional BOP stack and conventional riser.
  • the method may further comprise the step of removing the conventional BOP stack from the subsea wellhead.
  • the method may further comprise the step of coupling a surface BOP stack to the subsea wellhead via a high pressure riser.
  • the method may further comprise the step of completing the well through the surface BOP stack.
  • the method may further comprise the step of coupling a mudline closure device between the subsea wellhead and the high pressure riser.
  • Figure 1 is a partial schematic view of a conventional BOP stack and conventional riser deployed on a subsea wellhead for drilling operations;
  • Figure 2 is a partial schematic view of a surface BOP stack and a high pressure riser deployed on a subsea wellhead for lower completion operations;
  • Figure 3 is a partial schematic view of a surface BOP stack and a high pressure riser deployed on a subsea wellhead for upper completion operations;
  • Figure 4 is a partial schematic view of a surface BOP stack and a high pressure riser deployed on a subsea wellhead for workover or intervention operations.
  • first and second features are formed in direct contact
  • additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.
  • exemplary embodiments presented below may be combined in any combination of ways, i.e., any element from one exemplary embodiment may be used in any other exemplary embodiment, without departing from the scope of the disclosure.
  • High Pressure is defined as pressure at or above 15,000 psi pressure.
  • High Temperature is defined as temperature at or above 350 degrees F.
  • BOP stack is a blowout preventer stack, which may include one or more of a ram blowout preventer, an annular blowout preventer, and, when used during drilling, a lower marine riser package (LMRP).
  • LMRP lower marine riser package
  • a Conventional BOP stack refers to a subsea blowout preventer stack assembly rated for operation with wellbore pressures below 15,000 psi.
  • a Conventional Riser refers to a riser string that connects a Conventional BOP stack to a surface drilling unit.
  • the Conventional Riser is not designed for containing full wellbore pressures and must therefore be protected at all phases of the life of the well by other equipment, including but not limited to, a subsea BOP, a high pressure landing string, and/or dual redundant isolation valves such as commonly used in subsea test trees.
  • a High Pressure Surface BOP stack, or Surface BOP stack refers to a blowout preventer stack that is rated for operation with wellbore pressures at or above 15,000 psi and, during operations, is disposed on surface drilling unit.
  • a High Pressure Riser refers to a riser string that connects a High Pressure Surface BOP stack to a subsea wellhead.
  • the High Pressure Riser is designed for containing full wellbore pressure and therefore does not need to be protected during any phase of the life of the well.
  • a primary barrier consists of equipment for pressure containment and control that is critical.
  • a secondary barrier consists of equipment for pressure containment and control that is not critical.
  • Wellbore construction generally includes both a drilling phase and a completion phase.
  • the wellbore is drilled to a specified depth and lined with a series of casing strings that isolate the interior of the wellbore from the surrounding formation.
  • the completion phase can begin.
  • additional downhole tubulars and flow control devices are installed into the wellbore to enable the safe and efficient production of hydrocarbons from the surrounding formation.
  • high pressure formation fluids are prevented from entering the wellbore, either by the casing or by hydrostatic pressure created by the column of drilling fluid filling the wellbore and riser.
  • the wellbore, or at least a portion thereof is exposed to high pressure formation fluids.
  • the equipment and methods described herein allow High Pressure drilling, completion, and intervention work, and optionally High Pressure and High Temperature drilling, completion, and intervention work, to be done using conventional equipment, as well as a system including a High Pressure Surface BOP, a High Pressure Riser System, and a mudline closure device (MCD).
  • the equipment described in this disclosure is rated at or above 15,000 psi but is not necessarily rated beyond conventional temperatures (i.e., the equipment may not be rated for temperatures above 350 deg. F).
  • the High Pressure Riser may allow simplification of the design of the landing string used during completion, while providing an increased level of safety.
  • FIG. 1 a schematic view of a well 10 drilled through the seafloor 1 is illustrated during the construction phase, including drilling of the well 10, casing portions of the well 10 and/or lining portions of the well 10 and providing a tie-back from the liner to the casing.
  • Well 10 includes a subsea wellhead 12.
  • a Conventional BOP stack 16 is coupled to the wellhead by BOP connector 14.
  • the Conventional BOP stack 16 may include a ram BOP 11, an LMRP 13, and an annular BOP 15.
  • the LMRP 13 may form a section of a multi-section subsea BOP stack.
  • the annular BOP 15 may form a portion of the LMRP 13.
  • the LMRP 13 may include a hydraulic connector, jumper hoses for the choke, kill and auxiliary lines, and subsea control pods.
  • a Conventional Riser 18, including flex joint and riser adapter, is coupled to the Conventional BOP stack 16 and extends to a drilling rig 20 above the sea surface 5.
  • the Conventional riser 18 may be suspended via a tension ring 19 from the drilling rig 20.
  • An upper telescopic joint 23 and lower telescopic joint 17 may be used to allow heave compensation between a diverter 25 mounted on the drilling rig 20 and the tension ring 19.
  • Choke and kill lines 22 also extend from the Conventional BOP stack 16 to the drilling rig 20 along the Conventional Riser 18. Choke and kill lines 22 are connected to the choke and kill manifold 21.
  • the subsea wellhead 12, ram BOP 11, choke and kill lines 22, and choke and kill manifold 21 may form a primary barrier against high pressure blowouts of formation fluid.
  • the equipment forming the primary barrier is usually designed according to standards for containing pressure blowouts up to a rating of 15,000 psi, and to be operable even in the presence of a drill string.
  • the LMRP 13 including the annular BOP 15, the Conventional Riser 18, and the lower telescopic j oint 17 may form a secondary barrier against blowouts.
  • a High Pressure Riser 24 is coupled to the subsea wellhead 12 via a tubing head 46, a MCD 26 and emergency disconnect package (EDP) 28.
  • the EDP 28 is connected on top of the MCD 26 by EDP connector 29.
  • the MCD 26 is connected on top of the tubing head 46 by MCD connector 27.
  • the MCD 26 can provide two additional sets of rams with an independent control system, an acoustic control, and communications system, hydraulic flying leads, a remotely operated vehicle (ROV) control panel, and a subsea accumulator module.
  • ROV remotely operated vehicle
  • the MCD is preferably rated for containing a pressure equal to 20,000 psi.
  • the tubing head 46 is directly connected to the subsea wellhead 12 by tubing head connector 39.
  • the High Pressure Riser 24 extends a surface connector 45 where it is coupled to the drilling rig 20.
  • the surface connector 45 is coupled to a Surface BOP stack 30.
  • the surface BOP stack 30 includes a surface ram BOP 31 and a surface annular BOP 33.
  • the configuration shown in Figure 2 can be utilized to install the lower completion, which may include one or more strings of production liner or production tubing (not shown) that span the completion zone and isolate the lower pressure rated outer casing strings from high pressure production fluids.
  • the subsea wellhead 12, tubing head 46, MCD 26, EDP 28, High Pressure Riser 24, surface connector 45, and surface BOP stack 30 may form a primary barrier against blowouts.
  • the equipment forming the primary barrier should be designed according to standards for containing pressure at the subsea wellhead 12 at or above 15,000 psi.
  • the High Pressure Riser 24 and Surface BOP stack 30 of Figure 2 are also used during the installation of the upper completion string.
  • the upper completion string may contain various tubular members and equipment used to control the flow of formation fluids out of the wellbore.
  • the upper completion string may include tubing 34 that is supported in the wellbore by a tubing hanger 36.
  • the tubing 34 may be run and set into place using a running tool 38 that is mounted to the end of a landing string 40 by a shear joint 42 and retainer valves 44.
  • the upper completion string including the tubing 34, running tool 38, shear joint 42, retainer valves 44, and landing string 40, as well as the surface ram BOP 31 may form a primary barrier against blowouts.
  • the equipment forming the primary barrier should be designed according to standards for containing pressure at sea surface 5 at or above 15,000 psi.
  • the subsea wellhead 12, tubing head 46, MCD 26, EDP 28, High Pressure Riser 24, surface connector 45, and surface annular BOP 33 may form a secondary barrier against blowouts.
  • well construction may be accomplished using a Conventional BOP stack and Conventional Riser during the drilling phase, and then a High Pressure Riser and Surface BOP stack are used during the completion phase.
  • a Conventional BOP stack and Conventional Riser are used during the completion phase.
  • This allows a well to be drilled using a Conventional BOP stack and Conventional Riser and then completed with a Surface BOP stack and High Pressure Riser, which increases the safety and reliability of both phases of well construction.
  • the well 10 can be completed using a subsea tree 43 after the construction phase, and may be put in production.
  • the subsea tree 43 is connected on top of the tubing head 46 by tree connector 41.
  • the subsea tree 43 forms a portion of the primary barrier.
  • Figure 4 illustrates a High Pressure Riser 24 and a Surface BOP stack 30 configuration being used in workover or intervention operations with a well 10.
  • the High Pressure Riser 24 is coupled to the subsea tree 43 by a mudline closure device (MCD) 26 and emergency disconnect package (EDP) 28.
  • the EDP 28 is connected on top of the MCD 26 via EDP connector 29.
  • the MCD 26 is connected on top of the subsea tree 43 via MCD connector 27.
  • the subsea wellhead 12, tubing head 46, MCD 26, EDP 28, High Pressure Riser 24, surface connector 45, and surface annular BOP 33 may form a secondary barrier against blowouts. While the primary barrier during the workover and intervention operations is the landing string 40, the landing string 40 may be greatly simplified in view of the pressure rating on the High Pressure Riser 24. The inherent safety provided by the full pressure rating of the riser allows a reduction of the complexity of the landing string - i.e. the dual redundant valves in the subsea test tree can be replaced with a simple shear joint. [0036] Thus, in the disclosed embodiments, workover and intervention operations are accomplished using a High Pressure Riser and Surface BOP stack. The High Pressure Riser and Surface BOP stack are coupled to the subsea tree.

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  • 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)

Abstract

La complétion d'un puits (10), et la réalisation d'opérations de reconditionnement ou d'intervention d'un puits (10) requiert un empilement de BOP de surface (30) couplé à la tête de puits sous-marine (12) ou à un arbre sous-marin (43) par l'intermédiaire d'une colonne montante haute pression (24). Le puits (10) est achevé ou les opérations de reconditionnement ou d'intervention sont effectuées à travers l'empilement de BOP de surface (30).
PCT/US2018/035158 2017-05-30 2018-05-30 Procédé de forage et de complétion d'un puits WO2018222732A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
BR112019025337-8A BR112019025337B1 (pt) 2017-05-30 2018-05-30 Métodos para construir e completar um poço e para operações de recondicionamento ou intervenção com um poço

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201762512585P 2017-05-30 2017-05-30
US62/512,585 2017-05-30

Publications (1)

Publication Number Publication Date
WO2018222732A1 true WO2018222732A1 (fr) 2018-12-06

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ID=62683480

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Application Number Title Priority Date Filing Date
PCT/US2018/035158 WO2018222732A1 (fr) 2017-05-30 2018-05-30 Procédé de forage et de complétion d'un puits

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BR (1) BR112019025337B1 (fr)
WO (1) WO2018222732A1 (fr)

Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030051879A1 (en) * 2001-06-15 2003-03-20 Peter Azancot Systems and methods for constructing subsea production wells
US20050269096A1 (en) * 2002-09-13 2005-12-08 Milberger Lionel J Method and apparatus for blow-out prevention in subsea drilling/completion systems
US20060042791A1 (en) * 2004-09-02 2006-03-02 Stanley Hosie Tubing running equipment for offshore rig with surface blowout preventer
US7021402B2 (en) * 2003-12-15 2006-04-04 Itrec B.V. Method for using a multipurpose unit with multipurpose tower and a surface blow out preventer
WO2007103707A2 (fr) * 2006-03-02 2007-09-13 Shell Oil Company Systemes et procedes d'utilisation d'un cable ombilical
US20080271896A1 (en) * 2004-05-21 2008-11-06 Fmc Kongsberg Subsea As Device in Connection with Heave Compensation
WO2015147649A1 (fr) * 2014-03-25 2015-10-01 Aker Subsea As Appareil extracteur double

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030051879A1 (en) * 2001-06-15 2003-03-20 Peter Azancot Systems and methods for constructing subsea production wells
US20050269096A1 (en) * 2002-09-13 2005-12-08 Milberger Lionel J Method and apparatus for blow-out prevention in subsea drilling/completion systems
US7021402B2 (en) * 2003-12-15 2006-04-04 Itrec B.V. Method for using a multipurpose unit with multipurpose tower and a surface blow out preventer
US20080271896A1 (en) * 2004-05-21 2008-11-06 Fmc Kongsberg Subsea As Device in Connection with Heave Compensation
US20060042791A1 (en) * 2004-09-02 2006-03-02 Stanley Hosie Tubing running equipment for offshore rig with surface blowout preventer
WO2007103707A2 (fr) * 2006-03-02 2007-09-13 Shell Oil Company Systemes et procedes d'utilisation d'un cable ombilical
WO2015147649A1 (fr) * 2014-03-25 2015-10-01 Aker Subsea As Appareil extracteur double

Also Published As

Publication number Publication date
BR112019025337B1 (pt) 2022-04-26
BR112019025337A2 (pt) 2020-06-23

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