WO2021080752A1 - Open water coiled tubing control system - Google Patents

Open water coiled tubing control system Download PDF

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Publication number
WO2021080752A1
WO2021080752A1 PCT/US2020/053398 US2020053398W WO2021080752A1 WO 2021080752 A1 WO2021080752 A1 WO 2021080752A1 US 2020053398 W US2020053398 W US 2020053398W WO 2021080752 A1 WO2021080752 A1 WO 2021080752A1
Authority
WO
WIPO (PCT)
Prior art keywords
coiled tubing
tubing string
subsea
movement
reel
Prior art date
Application number
PCT/US2020/053398
Other languages
French (fr)
Inventor
Torleif CARLSEN
Original Assignee
Oceaneering International, 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 Oceaneering International, Inc filed Critical Oceaneering International, Inc
Priority to EP20879225.9A priority Critical patent/EP4028630A4/en
Priority to BR112022007453A priority patent/BR112022007453A2/en
Publication of WO2021080752A1 publication Critical patent/WO2021080752A1/en

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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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • E21B17/017—Bend restrictors for limiting stress on 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes

Definitions

  • Running coiled tubing (CT) in open water from a vessel, and then possibly directly through a subsea tree, as well as running CT by utilizing an injector on a vessel and an injector on the subsea tree/wellhead typically comprises concerns with maintenance of tension between vessel injector and subsea injector and/or reliance of passive heave control for the vessel injector.
  • a direct hydraulic control system e.g. a vessel to subsea assist jack, is impractical as the whip effect stress wave travels at near the speed of sound in the coiled tubing steel (damped by the surrounding water) whereas the transmission of a hydraulic pressure change command travels at the speed of sound in the hydraulic fluid. The former is approximately four times faster than the later.
  • Fig. l is a block diagram of an exemplary open water coiled tubing control system.
  • open water coiled tubing control system 1 comprises reel 20 configured to accept and spool/unspool coiled tubing string 100; one or more surface injectors 30 operatively in fluid communication with coiled tubing string 100; one or more reel tensioners 10 configured to control arch 110 formed by coiled tubing string 100 where control arch 110 is disposed in-between reel 20 and surface injector 30; and one or more controllers 40 configured to control reel tensioner 10 and allow movement of coiled tubing string 100 and surface injector 30 relative to each other without adding additional fatigue life consumption due to vessel heave.
  • Open water coiled tubing control system 1 typically uses surface injector motion to move coiled tubing string 100 into/out of the water.
  • coiled tubing string 100 is disposed about an outer surface of reel 20 but other embodiments are contemplated such as being disposed within or partially within reel 20.
  • Surface injector 30 may be mounted on heave compensator 32.
  • controller 40 is disposed intermediate reel 20 and surface injector
  • open water coiled tubing control system 1 further comprises subsea assist jack 50 to move coiled tubing string 100 into/out of subsea well 200.
  • open water coiled tubing control system 1 comprises a predetermined set of sensors (generally referred to but not specifically shown in the figure as callout “60”), which may be integrated into other components or separate.
  • the predetermined set of sensors 60 are operatively in communication with controller 40 and comprises one or more surface injector load sensors 61 configured to detect and provide data related to a load at surface injector 30; one or more coiled tubing string movement sensors 62 configured to detect and provide data related to movement of coiled tubing string 100 in reel tensioner 10 where the data comprise speed of movement; one or more surface injector movement sensors 63 configured to detect and provide data related to movement of surface injector 30; and one or more vessel movement sensors 64 configured to detect and provide data related to movement of vessel 210 where the data comprise active heave data and/or passive heave data.
  • the predetermined set of sensors 60 typically also comprise one or more subsea assist jack load sensors 65 configured to detect and provide data related to a load at subsea assist jack 50 and one or more subsea assist jack movement sensors 66 configured to detect and provide data related to movement of subsea assist jack 50.
  • open water coiled tubing control system 1 is deployed such as via vessel 210 which may also used to support surface injector 30.
  • Open water coiled tubing control system 1 receives information related to a load at surface injector 30 and, if present, at subsea assist jack 50; information on movement of coiled tubing string 100 in reel tensioner 10, surface injector 30, and, if present, subsea assist jack 50; and information on movement of vessel 210 or a compensation system such as heave compensator 32 used to support surface injector 30, e.g. either active or passive heave.
  • Open water coiled tubing control system 1 resolves all or a predetermined part of the information so received, e.g. by controller 40, to effect movement of coiled tubing string 100 into and/or out from subsea well 200 at a predetermined desired speed to achieve an outcome by having one or more commands issued to reel tensioners 10 by a single input from an operator. Typically, this is accomplished by an operator using controller 40 to issue one or more commands to reel 20, surface injectors 30, and reel tensioners 10 substantially simultaneously.
  • part of the resolved solution is to maintain coiled tubing string 100 at a predetermined tension in-between surface injector 30 and subsea assist jack 50.
  • controller 40 uses the information it receives from sensors 60 and determines a continuous movement rate of surface injector 30 versus an interrupted rate of subsea assist jack 50.
  • subsea assist jack 50 can be remotely disengaged from gripping coiled tubing string 100 when the force supplied by subsea assist jack 50 is no longer required to move coiled tubing string 100 into or out of subsea well 200. This can be accomplished by traditional means and/or by an instruction provided to controller 40 from a remote location or the like.
  • Open water coiled tubing control system 1 typically needs to have limited hysteresis to avoid a “whip effect” caused in part by an induced vessel movement resulting from wave action. Knowledge of the “whip effect” and the speed of translation on the stress wave through coiled tubing string 100 allows a determination of required system performance and operating limits of open water coiled tubing control system 1 versus the “sea state.”

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

A coiled tubing string may be moved into and/or out from water by deploying an open water coiled tubing control system (1) at sea such as via a vessel. The open water coiled tubing control system (1) comprises a reel (20) configured to accept a coiled tubing string (100), a surface injector (30), a reel tensioner (10) configured to control an arch (110) formed by the coiled tubing string between the reel and the surface injector, a controller (40), a subsea assist jack (50), and a predetermined set of a predetermined set of sensors. Motion of the surface injector and the subsea assist jack are used in part to move the coiled tubing string accepted by the reel into and/or out of a subsea well by receiving various information at the controller from the predetermined set of sensors and using the controller to resolve the received information to move the coiled tubing string into or out from the subsea well at a predetermined desired speed to achieve an outcome commanded by a single input from an operator

Description

OPEN WATER COILED TUBING CONTROL SYSTEM
RELATION TO OTHER APPLICATIONS
[0001] This application claims priority through United States Provisional Application
62/924,045 filed on October 21, 2019.
BACKGROUND
[0002] Running coiled tubing (CT) in open water from a vessel, and then possibly directly through a subsea tree, as well as running CT by utilizing an injector on a vessel and an injector on the subsea tree/wellhead typically comprises concerns with maintenance of tension between vessel injector and subsea injector and/or reliance of passive heave control for the vessel injector. A direct hydraulic control system, e.g. a vessel to subsea assist jack, is impractical as the whip effect stress wave travels at near the speed of sound in the coiled tubing steel (damped by the surrounding water) whereas the transmission of a hydraulic pressure change command travels at the speed of sound in the hydraulic fluid. The former is approximately four times faster than the later.
[0003] Existing systems do not disclose or render obvious an integrated control system that responds to a single operator input and controls.
FIGURES
[0004] Various figures are included herein which illustrate aspects of embodiments of the disclosed inventions.
[0004] Fig. l is a block diagram of an exemplary open water coiled tubing control system.
DESCRIPTION OF EXEMPLARY EMBODIMENTS
[0005] In a first embodiment, referring generally to Fig. 1, open water coiled tubing control system 1 comprises reel 20 configured to accept and spool/unspool coiled tubing string 100; one or more surface injectors 30 operatively in fluid communication with coiled tubing string 100; one or more reel tensioners 10 configured to control arch 110 formed by coiled tubing string 100 where control arch 110 is disposed in-between reel 20 and surface injector 30; and one or more controllers 40 configured to control reel tensioner 10 and allow movement of coiled tubing string 100 and surface injector 30 relative to each other without adding additional fatigue life consumption due to vessel heave.
[0006] Open water coiled tubing control system 1 typically uses surface injector motion to move coiled tubing string 100 into/out of the water.
[0007] Typically, coiled tubing string 100 is disposed about an outer surface of reel 20 but other embodiments are contemplated such as being disposed within or partially within reel 20. [0008] Surface injector 30 may be mounted on heave compensator 32.
[0009] In embodiments, controller 40 is disposed intermediate reel 20 and surface injector
30 above a water level such as by being connected to, or otherwise mounted on or to, vessel 210. [0010] In certain embodiments, open water coiled tubing control system 1 further comprises subsea assist jack 50 to move coiled tubing string 100 into/out of subsea well 200. [0011] In most embodiments, open water coiled tubing control system 1 comprises a predetermined set of sensors (generally referred to but not specifically shown in the figure as callout “60”), which may be integrated into other components or separate. Typically, the predetermined set of sensors 60 are operatively in communication with controller 40 and comprises one or more surface injector load sensors 61 configured to detect and provide data related to a load at surface injector 30; one or more coiled tubing string movement sensors 62 configured to detect and provide data related to movement of coiled tubing string 100 in reel tensioner 10 where the data comprise speed of movement; one or more surface injector movement sensors 63 configured to detect and provide data related to movement of surface injector 30; and one or more vessel movement sensors 64 configured to detect and provide data related to movement of vessel 210 where the data comprise active heave data and/or passive heave data. In embodiments comprising subsea assist jack 50, the predetermined set of sensors 60 typically also comprise one or more subsea assist jack load sensors 65 configured to detect and provide data related to a load at subsea assist jack 50 and one or more subsea assist jack movement sensors 66 configured to detect and provide data related to movement of subsea assist jack 50.
[0012] In the operation of exemplary methods, referring back to Fig. 1, in an embodiment, open water coiled tubing control system 1 is deployed such as via vessel 210 which may also used to support surface injector 30. Open water coiled tubing control system 1 receives information related to a load at surface injector 30 and, if present, at subsea assist jack 50; information on movement of coiled tubing string 100 in reel tensioner 10, surface injector 30, and, if present, subsea assist jack 50; and information on movement of vessel 210 or a compensation system such as heave compensator 32 used to support surface injector 30, e.g. either active or passive heave.
[0013] Open water coiled tubing control system 1 resolves all or a predetermined part of the information so received, e.g. by controller 40, to effect movement of coiled tubing string 100 into and/or out from subsea well 200 at a predetermined desired speed to achieve an outcome by having one or more commands issued to reel tensioners 10 by a single input from an operator. Typically, this is accomplished by an operator using controller 40 to issue one or more commands to reel 20, surface injectors 30, and reel tensioners 10 substantially simultaneously.
[0014] In currently contemplated methods, part of the resolved solution is to maintain coiled tubing string 100 at a predetermined tension in-between surface injector 30 and subsea assist jack 50. Typically, controller 40 uses the information it receives from sensors 60 and determines a continuous movement rate of surface injector 30 versus an interrupted rate of subsea assist jack 50.
[0015] In certain embodiments, subsea assist jack 50 can be remotely disengaged from gripping coiled tubing string 100 when the force supplied by subsea assist jack 50 is no longer required to move coiled tubing string 100 into or out of subsea well 200. This can be accomplished by traditional means and/or by an instruction provided to controller 40 from a remote location or the like.
[0016] Open water coiled tubing control system 1 typically needs to have limited hysteresis to avoid a “whip effect” caused in part by an induced vessel movement resulting from wave action. Knowledge of the “whip effect” and the speed of translation on the stress wave through coiled tubing string 100 allows a determination of required system performance and operating limits of open water coiled tubing control system 1 versus the “sea state.”
[0017] The foregoing disclosure and description of the inventions are illustrative and explanatory. Various changes in the size, shape, and materials, as well as in the details of the illustrative construction and/or an illustrative method may be made without departing from the spirit of the invention.

Claims

1. An open water coiled tubing control system (1), comprising: a. a reel (20) configured to accept a coiled tubing string (100); b. a surface injector (30) in fluid communication with the coiled tubing string; c. a reel tensioner (10) configured to control an arch (110) formed by the coiled tubing string between the reel and the surface injector; d. a controller (40) configured to control the reel tensioner and allow movement of the coiled tubing string and the surface injector relative to each other without adding additional fatigue life consumption due to vessel heave; and e. a predetermined set of sensors (60) operatively in communication with the controller (40), the predetermined set of sensors (60) comprising: i. a surface injector load sensor (61) configured to detect and provide data related to a load at the surface injector; ii. a coiled tubing string movement sensor (62) configured to detect and provide data related to movement of the coiled tubing string in the reel tensioner, the data comprising speed of movement; iii. a surface injector movement sensor (63) configured to detect and provide data related to movement of the surface injector; and iv. a vessel movement sensor (64) configured to detect and provide data related to movement of a vessel, the data comprising active heave data or passive heave data.
2. The open water coiled tubing control system of Claim 1, wherein the reel is configured to accept the coiled tubing string about an outer surface of the reel and/or to accept the coiled tubing string partially within the reel.
3. The open water coiled tubing control system of Claim 1, wherein the controller (40) is disposed intermediate the reel (20) and the surface injector (30).
4. The open water coiled tubing control system of Claim 1, wherein the controller (40) is connected or otherwise mounted to a vessel (210).
5. The open water coiled tubing control system of Claim 1, further comprising: a. a subsea assist jack (50) configured to move the coiled tubing string into or out of a subsea well (200); b. a subsea assist jack load sensor (65) configured to detect and provide data related to a load at the subsea assist jack; and c. a subsea assist jack movement sensor (66) configured to detect and provide data related to movement of the subsea assist jack.
6. The open water coiled tubing control system of Claim 6, wherein the subsea assist jack (50) is deployed into the water from the vessel.
7. A method moving a coiled tubing string into and/or out from water, comprising: a. deploying an open water coiled tubing control system (1) at sea with a vessel, the open water coiled tubing control system (1), comprising a reel (20) configured to accept a coiled tubing string (100), a surface injector (30) in fluid communication with the coiled tubing string and supported by the vessel, a reel tensioner (10) configured to control an arch (110) formed by the coiled tubing string between the reel and the surface injector, a controller (40) configured to control the reel tensioner and allow movement of the coiled tubing string and the surface injector relative to each other without adding additional fatigue life consumption due to vessel heave, a subsea assist jack (50) configured to move the coiled tubing string into or out of a subsea well, and a predetermined set of a predetermined set of sensors comprising a load sensor configured to detect and provide data related to a load at the surface injector, a coiled tubing string movement sensor configured to detect and provide data related to movement of the coiled tubing string in the reel tensioner, the data comprising speed of movement, a surface injector movement sensor configured to detect and provide data related to movement of the surface injector, a vessel movement sensor configured to detect and provide data related to movement of the vessel where the data comprise active heave data or passive heave data, a subsea assist jack load sensor configured to detect and provide data related to a load at the subsea assist jack, and a subsea assist jack movement sensor configured to detect and provide data related to movement of the subsea assist jack; b. using motion of the surface injector and the subsea assist jack to move a coiled tubing string accepted by the reel into and/or out of a subsea well (200) by: i. receiving information at the controller from the predetermined set of sensors representing a load at the surface injector and at the subsea assist jack; ii. receiving information at the controller from the predetermined set of sensors on movement of the coiled tubing string in the reel tensioner, the surface injector, and the subsea assist jack; iii. receiving information at the controller from the predetermined set of sensors on movement of the vessel used to support the surface injector; iv. using the controller to resolve the received information to move the coiled tubing string into or out from the subsea well at a predetermined desired speed to achieve an outcome commanded by a single input from an operator, the single input from the operator comprising a command sent to the reel, the surface injector, and the reel tensioner substantially simultaneously.
8. The method moving a coiled tubing string into and/or out of water of Claim 7, further comprising maintaining the coiled tubing string in a predetermined tension between the surface injector and the subsea assist jack.
9. The method moving a coiled tubing string into and/or out of water of Claim 7, further comprising using the controller to determine a continuous movement rate of the surface injector versus an interrupted rate of the subsea assist jack.
10. The method moving a coiled tubing string into and/or out of water of Claim 7, further comprising remotely disengaging the subsea assist jack from gripping the coiled tubing string when a force supplied by the subsea assist jack is no longer required to move the coiled tubing string into or out of the subsea well.
PCT/US2020/053398 2019-10-21 2020-09-30 Open water coiled tubing control system WO2021080752A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
EP20879225.9A EP4028630A4 (en) 2019-10-21 2020-09-30 Open water coiled tubing control system
BR112022007453A BR112022007453A2 (en) 2019-10-21 2020-09-30 OPEN WATER SPIRAL PIPE CONTROL SYSTEM

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201962924045P 2019-10-21 2019-10-21
US62/924,045 2019-10-21

Publications (1)

Publication Number Publication Date
WO2021080752A1 true WO2021080752A1 (en) 2021-04-29

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ID=75620725

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2020/053398 WO2021080752A1 (en) 2019-10-21 2020-09-30 Open water coiled tubing control system

Country Status (3)

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EP (1) EP4028630A4 (en)
BR (1) BR112022007453A2 (en)
WO (1) WO2021080752A1 (en)

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5975203A (en) * 1998-02-25 1999-11-02 Schlumberger Technology Corporation Apparatus and method utilizing a coiled tubing injector for removing or inserting jointed pipe sections
US20020029908A1 (en) * 1998-12-18 2002-03-14 Duane Bloom Electrically sequenced tractor
US20040040707A1 (en) * 2002-08-29 2004-03-04 Dusterhoft Ronald G. Well treatment apparatus and method
US20040065475A1 (en) * 2002-10-04 2004-04-08 Halliburton Energy Services, Inc. Method and apparatus for riserless drilling
US20150101799A1 (en) * 2013-10-15 2015-04-16 National Oilwell Varco, L.P. Coiled tubing injector with load sensing tubing guide
US20180080850A1 (en) * 2016-09-16 2018-03-22 Onesubsea Ip Uk Limited Conduit fatigue management systems and methods

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6116345A (en) * 1995-03-10 2000-09-12 Baker Hughes Incorporated Tubing injection systems for oilfield operations
GB0522971D0 (en) * 2005-11-11 2005-12-21 Qserv Ltd Apparatus and method
CA2971423C (en) * 2015-02-13 2019-08-13 Halliburton Energy Services, Inc. Real-time tracking and mitigating of bending fatigue in coiled tubing

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5975203A (en) * 1998-02-25 1999-11-02 Schlumberger Technology Corporation Apparatus and method utilizing a coiled tubing injector for removing or inserting jointed pipe sections
US20020029908A1 (en) * 1998-12-18 2002-03-14 Duane Bloom Electrically sequenced tractor
US20040040707A1 (en) * 2002-08-29 2004-03-04 Dusterhoft Ronald G. Well treatment apparatus and method
US20040065475A1 (en) * 2002-10-04 2004-04-08 Halliburton Energy Services, Inc. Method and apparatus for riserless drilling
US20150101799A1 (en) * 2013-10-15 2015-04-16 National Oilwell Varco, L.P. Coiled tubing injector with load sensing tubing guide
US20180080850A1 (en) * 2016-09-16 2018-03-22 Onesubsea Ip Uk Limited Conduit fatigue management systems and methods

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP4028630A4 *

Also Published As

Publication number Publication date
EP4028630A1 (en) 2022-07-20
EP4028630A4 (en) 2023-07-26
BR112022007453A2 (en) 2022-07-12

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