WO2018102353A1

WO2018102353A1 - Light weight subsea systems

Info

Publication number: WO2018102353A1
Application number: PCT/US2017/063608
Authority: WO
Inventors: Jeffrey Lloyd WEEKS; Chiz Chikwendu; Nemanya SEDOGLAVICH; Robert William COLBY; Matthew Blieske; Justin STROUD; John Giarratana; Martin CLEARY
Original assignee: Shell Oil Company; Shell Internationale Research Maatschappij B. V.
Priority date: 2016-12-01
Filing date: 2017-11-29
Publication date: 2018-06-07

Abstract

A subsea tool comprising: a cylindrical body; one or more casing anchors attached to the cylindrical body; and a modular attachment and associated systems and methods.

Description

LIGHT WEIGHT SUBSEA SYSTEMS

CROSS REFERENCE TO RELATED APPLICATIONS

[0001] This application claims the benefit of U.S. Provisional Application No. 62/428,793, filed December 1, 2016, which is incorporated herein by reference.

BACKGROUND

[0002] The present disclosure relates generally to light weight subsea systems. More specifically, in certain embodiments, the present disclosure relates to light weight subsea systems that are capable of being deployed from Category A vessels and actuating downhole tools through well control packages and associated methods.

[0003] Conventional workover operations are typically performed using bottom hole assemblies that are operated by drill pipe, riser, coiled tubing, and/or wireline systems. In order to deploy these systems, a Category C vessel type or greater is generally required. Each of these systems has their own advantages and disadvantages.

[0004] Coiled tubing and wireline systems are capable of offering electrical, data and fluid transfer to bottom hole assemblies. Wireline systems are capable of lowering tools by gravity to the well and are capable of applying an over-pull load similar to a winch. Coiled tubing systems can over/under-pull a bottom hole assembly within its tensile and buckling load limits, but they may offer poor position control in the wellbore. Drill pipe systems, on the other hand, can provide a rigid connection to the bottom hole assembly for relatively high over/under-pull but require the pipe to be deployed in short manually assembled segments. In all these systems, multiple retrieval/deployments are required to change out tools while completing a job.

[0005] Category C vessels, utilized for typical subsea abandonment operations, have one of the highest spread rate costs on the market. In addition, the construction of marine risers and/or drill pipes further increase the cost of subsea abandonment and similar workover operations.

[0006] It is desirable to develop a method and system that allows operators access to subsea wells through a well control package utilizing a Category A type vessel that combines the advantages of drill pipe, coiled tubing, and wireline systems while eliminating the significant disadvantages of those systems. SUMMARY

[0007] The present disclosure relates generally to light weight subsea systems. More specifically, in certain embodiments, the present disclosure relates to light weight subsea systems that are capable of being deployed from Category A vessels and actuating downhole tools through well control packages and associated methods.

[0008] In one embodiment, the present disclosure provides a subsea tool comprising: a cylindrical body; one or more casing anchors attached to the cylindrical body; and a modular attachment.

[0009] In another embodiment, the present disclosure provides a subsea system comprising: a vessel, a well containment system, an umbilical, a subsea tree, and a subsea tool.

[0010] In another embodiment, the present disclosure provides a method comprising: providing a subsea system, wherein the subsea system comprises a vessel, a well containment system, an umbilical, a subsea tree, and a subsea tool and performing a work over operation with the subsea tool.

BRIEF DESCRIPTION OF THE DRAWINGS

[0011] A more complete and thorough understanding of the present embodiments and advantages thereof may be acquired by referring to the following description taken in conjunction with the accompanying drawings.

[0012] Figure 1 is an illustration of a subsea tool in accordance with certain embodiments of the present disclosure.

[0013] Figure 2 is an illustration of a subsea system in accordance with certain embodiments of the present disclosure.

[0014] The features and advantages of the present disclosure will be readily apparent to those skilled in the art. While numerous changes may be made by those skilled in the art, such changes are within the spirit of the disclosure.

DETAILED DESCRIPTION

[0015] The description that follows includes exemplary apparatuses, methods, techniques, and/or instruction sequences that embody techniques of the inventive subject matter. However, it is understood that the described embodiments may be practiced without these specific details.

[0016] The present disclosure relates generally to light weight subsea systems. More specifically, in certain embodiments, the present disclosure relates to light weight subsea systems that are capable of being deployed from Category A vessels and actuating downhole tools through well control packages and associated methods.

[0017] In certain embodiments, the present disclosure describes a subsea well abandonment system that requires, at maximum, Category A vessel types. In certain embodiments, the system may operate with an umbilical and fit for purpose well containment system and does not require a riser or drill pipe. In certain embodiments, the system may affix to a subsea tree interface and utilize a specialized toolset to execute workover operations.

[0018] In certain embodiments, the specialized toolset may comprise a highly- automated umbilical deployed sub-system capable of light drilling and actuating downhole tools for extended periods of time. The system may employ multiple actuators and/or casing anchors to apply axial force, anchor to casing, and locomote through the wellbore in a way similar to the peristaltic behavior of a worm. In certain embodiments, a modular attachment may interface with the standard downhole tools currently available while also supporting the development of advanced downhole tools.

[0019] In certain embodiments, the sub-system may operate on existing available vessel supplied power, mud, and cementing systems while integrating an actuation and control system tolerant to typical downhole environments. The actuation and control system may be electrically powered, contained within the downhole system and communicate to the topside operators through a standard communication protocol. The system may be capable of managing axial and rotational reaction forces experienced during light drilling, cutting and downhole actuation while maintaining position control to a high degree of accuracy not found in manual drill pipe and coiled tubing operations.

[0020] There may be several advantages to the methods and systems described herein. In certain embodiments, the use of the methods and systems described herein may permit operators to reduces sum spread rate cost of abandonment operations by not requiring a MODU, may save operators significant amounts of time when compared to tripping drill pipe, may allow for precision bottom hole assembly position control compared to coiled tubing/wireline systems, may reduce dependency on operators, may reduce HSSE risks, may utilize universal interfaces for future development, may enhance ability to optimize performance, and may reduce surface infrastructure requirements.

[0021] In certain embodiments, the methods and systems disclosed herein may permit tools to extend through a 7 and 3/8 inch restriction found in a well control package and drill a 9 and 5/8 inch hole. In certain embodiments, the highly- automated umbilical deployed subsystem would combine the advantages of drill pipe, coiled tubing and wireline while eliminating significant disadvantages. In certain embodiments, the proposed subsea system is capable of precise position control while withstanding the mechanical loading experienced during light-duty workover operations. In certain embodiments, the subsea system may decrease the time required to reach a downhole area of interest and negate the need for topside operators to manually and directly control the precise position downhole equipment.

[0022] In certain embodiments, the present disclosure describes a subsea tool. Referring now to Figure 1, Figure 1 illustrates subsea tool 100. In certain embodiments, subsea tool 100 may comprise cylindrical body 110, first casing anchor 120, and second casing anchor 130. In certain embodiments, subsea tool 100 may further comprise piston assembly 140, umbilical 150, and hydraulic power unit 180.

[0023] In certain embodiments, cylindrical body 110 may comprise side wall 111, top 112, and bottom 113. In certain embodiments, cylindrical body 110 may have a length in the range of from 8 feet to 40 feet. In certain embodiments, cylindrical body 110 may have a length in the range of from 10 feet to 15 feet. In certain embodiments, cylindrical body 110 may define a chamber 101.

[0024] In certain embodiments, piston assembly 140 may be disposed within chamber 101. In certain embodiments piston assembly 140 may comprise piston rod 141 and piston head 142. In certain embodiments, piston head 142 may comprise one or more seals 143.

[0025] In certain embodiments, piston assembly 140 may divide chamber 101 into a top portion 102 and a bottom portion 103. In certain embodiments, top portion 102 may be located above piston head 142 and bottom portion 103 may be located below piston head 142.

[0026] In certain embodiments, top portion 102 may be filled with hydraulic fluid. In certain embodiments, top portion 102 may be in fluid communication with hydraulic power unit 180. In certain embodiments, bottom portion 103 may be filled with hydraulic fluid.

[0027] In certain embodiments, hydraulic power unit 180 may be connected to umbilical 150. In certain embodiments, umbilical 150 may pass through the middle of subsea tool 100. In certain embodiments, umbilical 150 may be in fluid communication with first casing anchor 120, second casing anchor 130, and/or downhole tool 170. In certain embodiments, umbilical 150 may comprise an electrical power, data, and drilling fluid circulation umbilical.

[0028] In certain embodiments, piston 140 may be able to transition from an un- extended positon to an extended position by increasing hydraulic pressure supplied to top portion 102 of chamber 101 from hydraulic power unit 180 via umbilical 150. In certain embodiments, piston 140 may be able to transition from an extended position to an un- extended position by decreasing hydraulic pressure supplied to top portion 102 of chamber

101 from hydraulic power unit 180 via umbilical 150.

[0029] In certain embodiments, piston rod 141 may be attached to or pass through first casing anchor 120. In certain embodiments, first casing anchor 120 may comprise an expanding casing anchor. In certain embodiments, first casing anchor 120 may be operated to transition from an expanded position to a closed position.

[0030] In certain embodiments, first casing anchor 120 may be able to transition from a closed position to an expanded position by increasing hydraulic pressure supplied to first casing anchor 120 from hydraulic power unit 180 via umbilical 150. In certain embodiments, first casing anchor 120 may be able to transition from an expanded position to a closed position by decreasing hydraulic pressure supplied to first casing anchor 120 from hydraulic power unit 180 via umbilical 150.

[0031] In certain embodiments, for example when first casing anchor 120 is an expanded position, first casing anchor 120 may have a diameter equal to the inner diameter of a casing. In certain embodiments, for example when first casing anchor 120 is in a closed position, first casing anchor 120 may have a diameter equal to the diameter of cylindrical body 110.

[0032] In certain embodiments, first casing anchor 120 may comprise attachment point 160. In other embodiments, piston rod 141 may comprise attachment point 160. In certain embodiments, a downhole tool 170 may be connected to attachment point 160. In certain embodiments, downhole tool 170 may comprise any conventional bottom hole assembly. In certain embodiments, downhole tool 170 may comprise a drill bit, a mud motor, or a drill collar. In certain embodiments, downhole tool 170 may comprise a non- abrasive water jet. In certain embodiments, downhole tool 170 may be used for drilling out surface plugs.

[0033] In certain embodiments, subsea tool 100 may comprise one, two, three, or more second casing anchors 130. In certain embodiments, umbilical 150 may pass through the one or more second casing anchors 130. In certain embodiments, second casing anchors 130 may comprise expanded casing anchors.

[0034] In certain embodiments, second casing anchors 130 may be able to transition from a closed position to an expanded position by increasing hydraulic pressure supplied to second casing anchors 130 from hydraulic power unit 180 via umbilical 150. In certain embodiments, second casing anchors 130 may be able to transition from an expanded position to a closed position by decreasing hydraulic pressure supplied to second casing anchors 130 from hydraulic power unit 180 via umbilical 150.

[0035] In certain embodiments, for example when second casing anchors 130 are in an expanded position, second casing anchors 130 may have a diameter equal to the inner diameter of a casing. In certain embodiments, for example when second casing anchors 130 are in a closed position, second casing anchors 130 may have a diameter equal to the diameter of cylindrical body 110.

[0036] In certain embodiments, tool 100 may be capable of traveling through a wellbore without the use of a drill pipe, riser, wireline, or coiled tubing. In certain embodiments, tool 100 may be operated to travel down a wellbore by, (1) expanding second casing anchors 130 if not expanded, (2) retracting first casing anchor 120, increasing the pressure in upper portion 102 of chamber 101 thereby allowing piston 140 to move to the extended positon, expanding first casing anchor 120, an expanding second casing anchors 130, and reducing the pressure in upper portion 102 of chamber 101, thereby allowing cylindrical body 110 to move relative to piston 140 thereby placing piston 140 in the un-extended position.

[0037] In certain embodiments, the present disclosure provides a subsea system. Referring now to Figure 2, Figure 2 illustrates subsea system 1000. In certain embodiments, subsea system 1000 may comprise vessel 1100, umbilical 1200, subsea tree 1300, and subsea tool 1400.

[0038] In certain embodiments, vessel 1100 may be floating on a sea surface 1001. In certain embodiments, vessel 1100 may be a Category A vessel type. In other embodiments, vessel 1100 may be a Category B vessel type. As used herein, the term Category A vessel type refers to a vessel capable of performing subsea completion/workover (C/WO) activities with wireline without the use of a riser system to surface, category B vessel type refers to a vessel capable of performing subsea C/WO activities utilizing a C/WO riser system in open sea, and Category C vessel types refers to a vessel capable of performing subsea CAVO activities utilizing a drilling BOP and marine riser.

[0039] In certain embodiments, subsea tree 1300 may be assembled on top of a subsea well 1305. In certain embodiments, well 1305 may be a temporarily abandoned well. In other embodiments, well 1305 may be a producing well.

[0040] In certain embodiments, subsea tree 1300 may comprise a well control package. In certain embodiments, the well control package may comprise a wireline lubricator or a BOP. In certain embodiments, the well control package is not a BOP and a BOP is not connected to subsea well 1305.

[0041] In certain embodiments, subsea tool 1400 may be disposed in subsea well

1305. In certain embodiments, subsea tool 1400 may comprise any combination of features discussed above with respect to subsea tool 100. In certain embodiments, subsea tool 1400 may be capable of passing through a restriction of well control package. In certain embodiments, umbilical 1200 may be capable of controlling subsea tool 1400 while subsea tool 1400 is disposed within subsea well 1305. In certain embodiments, umbilical 1200 may be connected to subsea tree 1300 or well control package or extend through well control package.

[0042] In certain embodiments, the present disclosure provides a method comprising providing a subsea system comprising a vessel, an umbilical, a subsea tree, and a subsea tool and performing a work over operation with the subsea tool.

[0043] While the embodiments are described with reference to various implementations and exploitations, it will be understood that these embodiments are illustrative and that the scope of the inventive subject matter is not limited to them. Many variations, modifications, additions and improvements are possible.

[0044] Plural instances may be provided for components, operations and/or structures described herein as a single instance. In general, structures and functionality presented as separate components in the exemplary configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the inventive subject matter.

Claims

What is claimed is:

1. A subsea tool comprising: a cylindrical body; one or more casing anchors attached to the cylindrical body; and a modular attachment.

2. The subsea tool of claim 1, wherein the one or more casing anchors comprises a first casing anchor and one or more second casing anchors.

3. The subsea tool of claim 1 or 2, wherein the cylindrical body comprises defines a chamber.

4. The subsea tool of claim 3, wherein a piston assembly is disposed within the chamber, wherein the piston assembly comprises a piston rod and a piston head.

5. The subsea tool of claim 4, wherein the piston rod passes through the first casing anchor.

6. The subsea tool of any one of claims 1-5, further comprising an umbilical fluidly connected to the one or more casing anchors.

7. The subsea tool of any one of claims 1-6, wherein the modular attachment comprises a bottom hole assembly.

8. The subsea tool of any one of claims 1-7, wherein the one or more casing anchors are capable of transitioning from a closed position to an open position.

9. A subsea system comprising: a vessel, a well containment system, an umbilical, a subsea tree, and the subsea tool of any one of claims 1-8.

10. A method comprising: providing a subsea system, wherein the subsea system comprises a vessel, a well containment system, and umbilical, a subsea tree, and the subsea tool of any one of claims 1-8, and performing a work over operation with the subsea tool.