WO2014089132A1

WO2014089132A1 - Tubing movement compensation joint

Info

Publication number: WO2014089132A1
Application number: PCT/US2013/072949
Authority: WO
Inventors: Dinesh R. Patel
Original assignee: Schlumberger Canada Limited; Services Petroliers Schlumberger; Schlumberger Holdings Limited; Schlumberger Technology B.V.; Prad Research And Development Limited; Schlumberger Technology Corporation
Priority date: 2012-12-04
Filing date: 2013-12-04
Publication date: 2014-06-12

Abstract

A tubing movement compensation joint ("TMCJ") includes a mandrel slidably received in an outer tubular and a lock securing the mandrel and the outer tubular in a fixed axial position relative to one another when in a locked position and the lock is hydraulically operated to an unlock position in response to an operational pressure applied to the lock. The lock may include a piston holding a latch in engagement with the outer tubular and the mandrel when in the locked position and the piston is moved to the unlock position when the operational pressure is applied.

Description

TUBING MOVEMENT COMPENSATION JOINT

BACKGROUND

[0001] This section provides background information to facilitate a better understanding of the various aspects of the disclosure. It should be understood that the statements in this section of this document are to be read in this light, and not as admissions of prior art.

[0002] Hydrocarbon fluids such as oil and natural gas are obtained from subterranean geological formations by drilling a well that penetrates the formation. After a wellbore is drilled, various types of well completion components are installed in the well to control fluid flow through the wellbore.

SUMMARY

[0003] In accordance with one or more embodiments a tubing movement compensation joint ("TMCJ") includes a mandrel slidably received in an outer tubular and a lock securing the mandrel and the outer tubular in a fixed axial position relative to one another when in a locked position and the lock is hydraulically operated to an unlock position in response to an operational pressure applied to the lock. A well completion system may include a tubular movement compensation joint ("TMCJ") interconnecting a first tubing section and a second tubing section of the tubing, the TMCJ is hydraulically operable to an unlock position permitting axial movement of the first tubing section and the second tubing section relative to one another. The lock may be unlocked in response to an annulus-to-annulus pressure. A method in accordance to one or more embodiments includes running a completion string into a well, the completion string having an upper completion and a lower completion, the upper completion having a tubing providing a throughbore, the tubing incorporating a tubing movement compensation joint ("TMCJ") interconnecting a first tubing section and a second tubing section of the tubing. Landing a tubing hanger of the upper completion and setting a packer in an annulus below the TMCJ and hydraulically unlocking the TMCJ thereby permitting axial movement of the first tubing section and the second tubing section relative to one another.

[0004] The foregoing has outlined some of the features and technical advantages in order that the detailed description of the tubing movement compensation joint that follows may be better understood. Additional features and advantages of the tubing movement compensation joint will be described hereinafter which form the subject of the claims of the invention. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of claimed subject matter.

BRIEF DESCRIPTION OF THE DRAWINGS

[0005] Embodiments of tubing movement compensation joints are described with reference to the following figures. The same numbers are used throughout the figures to reference like features and components. It is emphasized that, in accordance with standard practice in the industry, various features are not necessarily drawn to scale. In fact, the dimensions of various features may be arbitrarily increased or reduced for clarity of discussion.

[0006] Figure 1 illustrates a well system in which embodiments of tubing movement compensation joints ("TMCJ") can be utilized. [0007] Figure 2 is a schematic illustration of a TMCJ locked and in a mid-position in accordance with one or more embodiments.

[0008] Figure 3 is a schematic illustration of a TMCJ unlocked and in a mid-position in accordance with one or more embodiments.

[0009] Figure 4 is a schematic illustration of a TMCJ unlocked and in a contracted position in accordance with one or more embodiments.

[0010] Figure 5 is a schematic illustration of a TMCJ unlocked and in an expanded position in accordance with one or more embodiments.

[0011] Figure 6 is a schematic illustration of a TMCJ unlocked via a contingency release in accordance to one or more embodiments.

[0012] Figure 7 is a schematic illustration of a TMCJ actuated to an unlock position via hydraulic control line pressure in accordance to one or more embodiments.

[0013] Figure 8 is a schematic illustration of a TMCJ actuated to an unlock position via tubing- annulus differential pressure in accordance to one or more embodiments.

DETAILED DESCRIPTION

[0014] It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.

[0015] In the specification and appended claims: the terms "connect," "connection," "connected," "in connection with," and "connecting" are used to mean "in direct connection with" or "in connection with via one or more elements"; and the term "set" is used to mean "one element" or "more than one element." Further, the terms "couple," "coupling," "coupled," "coupled together," and "coupled with" are used to mean "directly coupled together" or "coupled together via one or more elements". As used herein, the terms "up" and "down," "upper" and "lower," "upwardly" and downwardly," "upstream" and "downstream," "above" and "below," and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.

[0016] Wellbore completions utilize a string of tubulars that are in fluid communication between some depth within the well and the surface. Contraction-type joints may be used somewhere along these strings to accommodate axial expansion and/or contraction of the tubular string. Such contractions and expansions may result from thermal fluctuations in the well. In some cases, contraction joints utilize shear pins to keep the contraction joint locked while running in the hole. Once on depth the completion lands out on top of a no-go stop or lower completion packer and weight is set-down to shear the pins and unlock the contraction joint. This allows lowering the upper completion and tubing hanger to land out the tubing hanger in the wellhead without buckling the tubing.

[0017] The drag force generated by running the completion in deviated, horizontal, or S-shape trajectory wells can be high and may shear the pins and unlock the contraction joint while running the completion in the hole. This requires pulling the completion out of the well to reset the contraction joint in the locked position. Also, in some applications it is necessary to land the tubing hanger before setting the production packer for example to prevent well control issues.

[0018] Referring generally to Figure 1, an example of an embodiment of a well completion system 6 is illustrated as including a tubing movement compensation joint ("TMCJ"), generally denoted by the numeral 10, that can be hydraulically unlocked. The well completion system can be used in a variety of well applications, including onshore and offshore applications. In Figure 1, the completion system is illustrated as deployed in a generally vertical wellbore of a multi- zone well, however, the completion system may be deployed in a variety of wells including deviated wells to facilitate production, servicing, and/or injection operations. In accordance to some embodiments, the tubing movement compensation joint is utilized in a single trip completion system. A single trip completion system requires only a single trip into the well for purposes of installing what is considered the upper and lower completions. [0019] As an example, Figure 1 depicts a well 8, which includes at least one wellbore 12 that extends to and/or through one or more earthen formations 14. Extending from a surface 16 is conductor casing 18, which may provide support for a wellhead 20. Casing 22 is run inside of conductor casing 18 and extends from wellhead 20 to a position below conductor casing 18. In the example of Figure 1, casing 22 extends to earthen formations 14. Fluid communication between the earthen formations and the bore of casing 22 is provided through openings 24 formed in casing 22 adjacent to the earthen formations 14.

[0020] A completion string or system 26 is illustrated deployed casing 22 from a tubing hanger 25 landed at wellhead 20. Completion string 26 includes a lower completion 28 and an upper completion 30. Tubing movement compensation joint ("TMCJ") 10 is incorporated in the upper completion. In the unlocked position TMCJ 10 provides for a range of axial expansion and/or contraction in the upper completion. In accordance to one or more embodiments, TMCJ is hydraulically actuated to the unlocked position allowing for axial expansion and/or contraction of the upper completion. In accordance to embodiments, TMCJ 10 can be unlocked without requiring setting down weight on the TMCJ.

[0021] Lower completion 28 may include a wide variety of components, systems, and arrangements of components and systems depending on the specific application for which it is designed. Accordingly, components, systems and arrangements are illustrated and described as examples and should not be construed as limiting the lower completion to the embodiment illustrated. By way of example, lower completion 28 includes a polished bore receptacle ("PBR") 32 for slidably receiving the upper completion and a latch 34, e.g., anchor latch, securing the upper completion 30 to lower completion 28. Lower completion 28 may include a lower hydraulic wet connect portion 36 coupled to individual or multiple lower hydraulic line segments, such as hydraulic control line segments 38 and/or chemical injection line segments 40. Lower completion 28 may include a lower electrical coupler 42, e.g. inductive coupler, coupled to individual or multiple lower electrical line segments 44.

[0022] Depending on the application, lower completion 28 may include a variety of other components, such as a lower completion packer 46, e.g., production packer, positioned to seal against the interior of casing 22. Packer 46 provides an annular barrier between the upper casing-tubing annulus 23 and the lower completion annulus that is in communication with formations 14. Lower completion 28 may include a barrier valve 48, e.g. a formation isolation valve, which may be controlled to close the lower completion with respect to fluid flow through the central flow passage or bore 50 of the lower completion. Depicted lower completion 28 includes flow control valves 52 and chemical injection valves 54. Various other components may also be employed in lower completion, for example, sensors, gauges, and power and telemetry devices.

[0023] Upper completion 30 includes a tubing 55 having an upper end 56 connected to tubing hanger 25 and a lower end 58 for sealing connection to the lower completion 28. In the Figure 1 example, lower end 58 is sealingly disposed in PBR 32 and connected via latch 34 with lower completion 28. Depicted upper completion 30 includes upper hydraulic wet connect portions 60 and upper electrical connect 62, e.g., inductive couplers, proximate lower end 58. Upper hydraulic wet connect portions 60 are coupled to upper hydraulic control line segments 66 (see, e.g., FIG. 2) and upper chemical injection line segments 67 (see, e.g., FIG. 2) which may be included in an upper control line 64. Upper electrical connect 62 may be coupled to individual or multiple upper electrical segments 68 (see, e.g., FIG. 2), which are carried in the upper control line 64. Completion string 26 has a hydraulic-electric wet mate ("HEWM") 70 formed by the upper hydraulic and electrical connects and the lower hydraulic and electrical connects. Upper completion 30 may include additional devices, for example and without limitation, a surface controlled subsurface safety valve ("SCSSV") 72 and additional valves 74, such as a gas lift valves and circulating valves.

[0024] Tubing movement compensation joint 10 is incorporated in tubing 55 of the upper completion between the upper end 56 and the lower end 58 in the example illustrated in Figure 1. A central bore or passageway 76 is coaxially formed through TMCJ 10 and tubing 55. TMCJ 10 can be incorporated into tubing 55 in various manners. For example, and without limitation, TMCJ may have threaded ends for connecting within tubing string 55. For example, in Figure 1 TMCJ 10 interconnects the first tubing section 53 and the second tubing section 57 to form a continuous tubing 55. In the locked position, TMCJ 10 holds the first and second tubing sections axially stationary relative to one another and in the unlocked position TMCJ 10 permits axial movement of the upper and lower tubing section relative to one another. In some embodiments, hydraulic and electrical liens are run on the outside of the production tubing. In this case TMCJ 10 allows tubing movement compensation and also hydraulic and electric line extension and contraction relative the tubing movement. This may be accomplished by forming a coil of the hydraulic and electric control line. [0025] Figure 2 illustrates an embodiment of TMCJ 10 in a locked position for example as the completion string 26 (FIG. 1) is being deployed in the wellbore. TMCJ 10 includes a tubular seal mandrel 80 slidably disposed with an outer tubular 82 and a lock 84 to secure the seal mandrel and the outer tubular in a fixed and stationary axial position relative to one another. In this example, TMCJ 10 is locked in a mid-position relative to a contracted position, e.g. FIG. 4, and an expanded position, e.g. FIG. 5. As will be understood by those skilled in the art with benefit of this disclosure, TMCJ may be locked in a contracted or an expanded position. With reference to Figure 1, first tubular section 53 is illustrated as the upper section of the upper completion and second tubular section 57 is illustrated as the lower section, however, it will be recognized by those skilled in the art with benefit of the disclosure that the orientation of TMCJ is not limited to the example of Figure 1.

[0026] Outer tubular 82 includes a first end 86 connected to a first tubular section 53 of a tubular 55 and a second end 88 having a seal 90 forming an internal seal surface 92. Outer tubular 82 includes an internal recess 94 extending radially outward from internal seal surface 92 to the recessed outer tubular and axially between a first shoulder 96 proximate the first end and a second shoulder 98 located toward the second end.

[0027] Seal mandrel 80 has a first end 100 in connection with a second tubular section 57 of tubular 55 and a stop nut 102 located proximate a second end 101 of the seal mandrel. Stop nut 102 extends radially outward from the axial bore 76 of the TMCJ. Stop nut 102 is positioned in recess 94 of outer tubular 82 and the outer surface of seal mandrel 80 is in sealing contact with seal surface 92. With additional reference to Figure 1, hydraulic communication between the throughbore 76 of TMCJ 10 and the tubing-casing annulus 23 is blocked at sealing surface 92.

[0028] Lock 84 is illustrated in Figure 2 in the locked position securing seal mandrel 80 to outer tubular 82 for example via a shroud 104, or housing. Shroud 104 is depicted extending axially from second end 88 of the outer tubular. Shroud 104 may be connected to outer tubular 82 in various manners such as, and without limitation threading and/or via shear device 132. Shear device 132 may be incorporated for use if the hydraulic unlock fails.

[0029] Lock 84 is disposed with seal mandrel 80 and includes a latch 106, e.g. a collet or other spring mechanism, moveable from a position engaged with outer tubular 82 to a disengaged position. For example, lock 84 may include a tubular sub connecting seal mandrel 80 with second tubular section 57.

[0030] Figure 2 illustrates latch 106 expanded outward and engaging shroud 104 at a connection 108. Connection 108 is illustrated as a dimple, recess, or hole in shroud 104. Lock 84 also includes a piston 110 that is moveable from a locked position urging latch 106 into engagement with the shroud to an unlocked position, e.g., Figures 3-5, allowing the latch to collapse or otherwise disengage from the shroud allowing reciprocating axial movement of the seal mandrel relative to the outer tubular.

[0031] Lock 84 includes a first chamber 112 in communication with a first piston side 114 and a second chamber 116 (FIG. 3) in communication with a second piston side 118 (FIG. 3). Seal members, generally denoted by the numeral 120, may be utilized to provide pressure seals. Pressure on first piston side 114 urges the piston into the lock position and pressure acting on second piston side 118 urges the piston away from the latch to the unlocked position. First chamber 112 is sealed and second chamber 116 is in selective pressure communication with an operational pressure. For example, in Figure 2 the operational pressure is the pressure exterior of throughbore 76, for example annulus 23 pressure. The operational, or control, pressure is in communication with the second chamber through a port 122. A blocking device 124 is provided at port 122 to control the application of the operational pressure. Blocking device 124 may include various devices including without limitation a hydraulic or electronic rupture disc. For the purpose of description, blocking device 124 will be described as a hydraulic rupture disc. TMCJ 10 may include more than one port 122 and blocking device 124 for redundancy. For example, Figure 2 illustrates two ports having blocking devices 124. When blocking device 124 is removed, e.g. opened, annulus 23 pressure is communicated to second chamber 116 and second piston side 118. Accordingly, in Figures 2-6, piston 110 is moved to the unlocked position in response to a differential pressure applied to the lock exterior of the throughbore of the TMCJ, e.g. an annulus-to-annulus differential pressure.

[0032] In accordance to one or more embodiments, TMCJ 10 may include an anti-rotation device to prevent rotational movement of seal mandrel 80 and outer tubular 82 relative to one another. For example, a key or pin 126 may extend from seal mandrel 80, e.g. from the lock sub, into an axial slot 128 formed in the shroud.

[0033] In accordance to one or more embodiments, shroud 104 is disposed about control line(s) 64 to protect the control lines from debris or entanglement. For example, a portion of the control line(s) 64 may be disposed in a cavity 130 formed radially between shroud 104 and seal mandrel 80 and axially between the second end 88 of the outer tubular and the lock sub. In the depicted example, control line(s) 64 include one or more hydraulic, chemical, electric, fiber optic, or other type of control lines grouped together. For example the individual segment lines may be encapsulated in a material and configured to accommodate cyclic loading. Reference may be made to US 8,061,430 for descriptions of non-limiting examples of control line assemblies.

[0034] An example of operation of a TCMJ 10 in accordance to one or more embodiments is now described with reference to Figures 1 to 5. Completion string 26 is run into wellbore 12 in a locked position, for example locked in a mid-position as shown in Figure 2. Tubing hanger 25 is landed at wellhead 20. Packer 46 is set, for example by applying tubing pressure against a closed lower completion. Lower completion may be closed in various manners including without limitation, closing the flow control valves 52, a closed barrier valve 48, or other barrier provided below packer 46. Blocking device 124, for example a rupture disc, is set at a rupture pressure above hydrostatic pressure. For example, blocking device 124 may be set at a rupture pressure of about 2,000 psi greater than hydrostatic pressure. Pressure can then be applied to the annulus 23 from wellhead 20 to test packer 46. To hydraulically unlock the TMCJ, an operational annulus pressure can then be applied to exceed the rupture pressure of blocking device 124 thereby opening blocking device 124 and communicating annulus 23 pressure to second chamber 116 and against second piston side 118. In response to the applied annulus 23 pressure, piston 110 is moved to the unlocked position and latch 106 is disengaged from shroud 104 and outer tubular 82 as illustrated for example in Figure 3. In this example, piston 110 is moved in response to the annulus-to-annulus differential pressure created across the piston. In the unlocked position of Figure 3, seal mandrel 80 and second tubing section 57 can axially move relative to outer tubular 82 and first tubing section 53 allowing tubing 55 and thereby upper completion 30 to axially expand and contract. Figure 4 illustrates TMCJ 10 in a fully contracted position, with stop nut 102 positioned proximate to first shoulder 96 and first end 86 of outer tubular 82. TMCJ 10 is illustrated in a fully expanded position in Figure 5 with stop nut 102 abutting second shoulder 98.

[0035] Figure 6 illustrates an example of a contingent mechanism for unlocking TMCJ 10. TMCJ 10 may include a contingent shear mechanism in case of failure to unlock TMCJ 10 via hydraulic lock 84. For example, if piston seals 120 leak during deployment then the hydraulic lock 84 may fail. It is noted that in the embodiment of Figures 2-6, the piston seals 120 do not need to maintain a seal after deployment of the completion string and operating the lock 84 to the unlock position because an annulus-to-tubing seal is maintained across TMCJ 10 at seal 98 and sealing surface 92. TMCJ 10 may also fail to unlock due to failure to open blocking device(s) 124 or due to binding. To utilize the contingency unlock feature, if available, the operator can apply weight to upper tubing section 53 to part a shear device 132 connecting for example shroud 104 and outer tubular 82. As illustrated in Figure 6, when shear device 132 has parted seal mandrel 80 and shroud 104, which remain engaged via lock 84, are free to move in unison relative to outer tubular 82. Axial movement remains available between the fully contracted and expanded positions. The parting force of shear device 132 may be selected to minimize the risk of parting when running the completion into the well since it is provided as a secondary or contingent mechanism for unlocking the TMCJ upon failure to hydraulically unlock the TMCJ. [0036] Figure 7 illustrates an embodiment of TMCJ 10 utilizing a hydraulic pressure supplied via a control line to operate lock 84 to the unlock position. An upper hydraulic control line segment 66 is illustrated in communication with second side 118 (FIG. 3) of piston 1 10 through second chamber 116. Hydraulic pressure can be applied via the control line to create the operational differential pressure across piston 110 to free latch 106 and unlock TMCJ 10.

[0037] Figure 8 illustrates an example of a TMCJ 10 utilizing tubing to annulus differential pressure to actuate hydraulic lock 84 to unlock the TMCJ. Annulus 23 pressure acts against first side 114 of piston 110. The pressure in throughbore 76, i.e. tubing pressure, is in communication through passage 134 with second chamber 116 to act against second piston side 118. To operate to the unlocked position, tubing pressure in excess of annulus 23 pressure is applied via throughbore 76 and path 134 to the second side of piston 110. A seal at second chamber 116 is maintained after unlocking the TMCJ to avoid communication between annulus 23 and tubing throughbore 76 at TMCJ 10.

[0038] The foregoing outlines features of several embodiments of tubing movement compensation joints so that those skilled in the art may better understand the aspects of the disclosure. Those skilled in the art should appreciate that they may readily use the disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the disclosure. The scope of the invention should be determined only by the language of the claims that follow. The term "comprising" within the claims is intended to mean "including at least" such that the recited listing of elements in a claim are an open group. The terms "a," "an" and other singular terms are intended to include the plural forms thereof unless specifically excluded.

Claims

WHAT IS CLAIMED IS:

1. 1. A tubing movement compensation joint ("TMCJ") (10), the TMCJ comprising: a mandrel (80) slidably received in an outer tubular (82), the mandrel and the outer

tubular having a throughbore (76); and

a lock (84) securing the mandrel and the outer tubular in a fixed axial position relative to one another when in a locked position and the lock is hydraulically operated to an unlock position in response to an operational pressure applied to the lock.

2. The TMCJ of claim 1, wherein the operational pressure is applied from exterior (23) of the throughbore.

3. The TMCJ of claim 1, comprising a seal (90) between the mandrel and the outer tubular, wherein the lock is positioned exterior of the seal relative to the throughbore.

4. The TMCJ of claim 1, wherein the lock comprises a piston (110) holding a latch (106) in engagement with the outer tubular and the mandrel when in the locked position and the piston is moved to an unlock position when the operational pressure is applied to the piston.

5. The TMCJ of claim 4, wherein the operational pressure is applied through a control line (66).

6. The TMCJ of claim 4, wherein the operational pressure is applied to the piston from exterior (23) of the throughbore.

7. The TMCJ of claim 4, wherein the operational pressure is applied to the piston from the throughbore.

8. The TMCJ of claim 1, further comprising a contingent shear mechanism (132) securing the outer tubular and the mandrel in a fixed axial relation, wherein the contingent shear mechanism can be released to allow relative movement between the outer tubular and the mandrel while the lock is in the locked position.

9. The TMCJ of claim 1, comprising:

a seal (90) between the mandrel and the outer tubular, wherein the lock is positioned exterior of the seal relative to the throughbore; and

the lock comprises a piston (110) holding a latch (106) in engagement with the outer tubular and the mandrel when in the locked position and the piston is moved to an unlock position when the operational pressure is applied to the piston.

10. The TMCJ of claim 9, wherein:

the outer tubular forms a recess (94) axially between a first shoulder (96) and a second shoulder (98) and radially outward from an internal sealing surface (92) of the seal; and the mandrel having a first end (100) positioned exterior of the outer tubular and a stop nut (102) positioned in the recess.

A well completion system (26), the system comprising:

a tubing (55) having a throughbore (76);

a tubular movement compensation joint ("TMCJ") (10) interconnecting a first tubing section (53) and a second tubing section (57) of the tubing, the TMCJ is hydraulically operable to an unlock position permitting axial movement of the first tubing section and the second tubing section relative to one another;

the TMCJ comprising:

a mandrel (80) slidably received in an outer tubular (82);

a sealing surface (92) between the mandrel and the outer tubular; and

a lock (84) positioned exterior of the sealing surface relative to the throughbore, the lock securing the mandrel and the outer tubular in a fixed axial position relative to one another when in a locked position and the lock is hydraulically operated to the unlock position in response to an operational pressure applied to the lock.

The system of claim 11, wherein the lock comprises a piston (110) holding a latch (106) in engagement with the outer tubular and the mandrel when in the locked position and the piston is moved to an unlock position when the operational pressure is applied to the piston.

13. The system of claim 11, wherein the operational pressure is applied from exterior of the throughbore.

14. The system of claim 11, wherein the mandrel has a stop nut (102) positioned in the outer tubular between an axially spaced apart first shoulder (96) and a second shoulder (98).

15. The system of claim 11 , wherein:

the outer tubular forms a recess (94) axially between a f first shoulder (96) and a second shoulder (98) and radially outward from the sealing surface;

the mandrel having a first end (100) positioned exterior of the outer tubular and a stop nut (102) positioned in the recess; and

the lock comprises a piston (110) holding a latch (106) in engagement with the outer tubular and the mandrel when in the locked position and the piston is moved to the unlock position when the operational pressure is applied to the piston.

16. A method, comprising :

running a completion string (26) into a well, the completion string comprising an upper completion (30) and a lower completion (28), the upper completion having a tubing (55) providing a throughbore (76), the tubing incorporating a tubing movement compensation joint ("TMCJ") (10) interconnecting a first tubing section (53) and a second tubing section (57) of the tubing; landing a tubing hanger (25) of the upper completion and setting a packer (46) in an annulus (23) below the TMCJ; and

hydraulically unlocking the TMCJ permitting axial movement of the first tubing section and the second tubing section relative to one another.

The method of claim 16, wherein the hydraulically actuating comprises applying an operational pressure to the annulus.

The method of claim 16, wherein the TMCJ comprises:

a mandrel (80) slidably received in an outer tubular (82);

a sealing surface (92) between the mandrel and the outer tubular; and

a lock (84) positioned exterior of the sealing surface relative to the throughbore, the lock securing the mandrel and the outer tubular in a fixed axial position relative to one another when in a locked position.

The method of claim 18, wherein the lock comprises a piston (110) holding a latch (106) in engagement with the outer tubular and the mandrel when in the locked position, wherein the hydraulically unlocking comprises applying an operational pressure to the piston. The method of claim 19, wherein the hydraulically unlocking comprises applying the operational pressure to the piston from one selected of the annulus, a control line, and the throughbore.