Patent Application
20180045013
The field of invention relates to offshore riser systems used in the oil and gas industry.
The present invention relates to an apparatus and method particularly but not exclusively for use in the moon pool area of an offshore vessel used to install and support a riser system used to produce hydrocarbons from a subsea well to a floating production facility or vessel on the sea surface and more particularly the invention relates to seeking to improve safety by allowing the possibility of halting and diverting the flow of hydrocarbon product to or below the drill floor and also providing the possibility of remote disconnection of the top level equipment on the drill floor from the riser system below and therefore allowing the possibility of work to be safely carried out on the top level equipment and/or the upper end of the riser system on the drill floor without the heave hazard associated with sea and vessel movement relative to the riser system.
Conventionally, hydrocarbons are produced from a subsea well through a wellhead. A primary flow control system in the form of a christmas tree is located at the wellhead and which controls the flow of hydrocarbon product from the subsea well through the wellhead and through the christmas tree into a riser system. The riser system consists of a sufficient length of flexible riser in the form of a flexible flow line or pipeline and which connects the christmas tree to a floating production facility or vessel located on the sea surface such that the riser system delivers the hydrocarbon product to the floating facility or vessel. The riser system is typically installed by a drill ship having a moon pool located in its center where all the equipment that is required when installing a riser system such as a lower riser package (LRP) and an emergency disconnect package (EDP) and the flexible riser itself can be lowered from the drill ship through the moon pool into the sea and down to the christmas tree.
Conventionally, work on the upper end of the riser system such as connecting in or swapping out required top level equipment is normally carried out with the drill ship moving relative to the sea bed/riser system because of the sea swell and this causes significant safety and operational problems when installing/changing such top level equipment and therefore sea conditions have to be calm to proceed with any degree of safety.
It would therefore be desirable to be able to safely work on the upper end of the riser system in conditions with some sea swell.
According to a first aspect of the present invention there is provided a valved tree member for inclusion in a riser system and suitable for use in the region of a moon pool on a floating vessel, the valved tree member comprising:
one or more valve members adapted to selectively permit and prevent flow of fluid there through, and
one or more moveable stab members adapted to respectively selectively provide a sealed fluid communication path between a throughbore of the riser system and the one or more valve members.
Preferably, the valved tree member comprises a body member upon which the said one or more valves are mounted and typically, the one or more valve members mounted thereon comprise a longitudinal axis arranged substantially perpendicularly to a longitudinal axis of the riser system at the point at which the valved tree member is included in the riser system. Typically, the said one or more valve members are connected to the body member by a tubular coupling having a throughbore and more preferably, the said moveable stab member is located within the throughbore of the tubular coupling. Preferably, the said moveable stab member is arranged to selectively engage with a port provided in the riser system. More preferably, the port is included at a suitable location in the riser system and comprises at least an aperture through a sidewall of the riser system. Typically, the said moveable stab member is arranged to selectively sealingly engage with the port provided in the riser system. Typically, the said moveable stab member is arranged to selectively move radially inwards toward the longitudinal axis of the riser system is a direction substantially perpendicular to the longitudinal axis of the riser system to sealingly engage with the port having an aperture formed through the sidewall of the riser system such that fluid in the throughbore of the riser system may flow in a sealed manner from the throughbore of the riser system through the moveable stab member and into the said one or more valves mounted on the valved tree member.
Preferably, a flow diverter member is included in the riser system, the flow diverter member comprising a substantially vertical tubular member having a longitudinal axis substantially parallel with and more preferably substantially co-incident with the longitudinal axis of the riser system at the point at which the flow diverter member is included in the riser system and more preferably the flow diverter member further comprises a cross tubular member which is more preferably arranged with its longitudinal axis to be substantially perpendicular to the longitudinal axis of the substantially vertical tubular member. Preferably, the cross tubular member provides said port or aperture at each end thereof. Typically, the flow diverter member comprises three or more (and more preferably only four) fluid entry/exit points where two are provided by each end of the substantially vertical tubular member and two are provided by each end of the cross tubular member and typically, the respective throughbores of the cross tubular member and the substantially vertical tubular member intersect one another.
Preferably, the valved tree member is selectively coupled to a housing member provided on the floating vessel and more preferably, the valved tree member comprises a selective locking system to selectively lock the valved tree member to the said housing member of the floating vessel. Typically, the valved tree member will be locked to the said housing member when the riser system is being run into the body of water on which the vessel is floating, the riser system being run in through a throughbore of the valved tree member and through the moon pool of the floating vessel.
Preferably, once the one or more valves of the valved tree member are in sealed fluid communication with the throughbore of the riser system, the selective locking system may be unlocked to release the valved tree member from engagement with the housing member and one or more tension supporting members are provided to support the weight of the valved tree member. Preferably, the said one or more tension supporting members permit relative movement, typically relative vertical movement, to occur between the valved member (which is now secured to the riser system) and the floating vessel such that the one or more tension supporting members also bear at least a portion of the weight of the riser system and thereby compensate for relative heave between the riser system and the floating vessel.
According to a second aspect of the present invention there is provided a telescoping device for inclusion in a riser system, the telescoping device comprising:
an inner member telescopingly provided in an outer member;
the inner member being moveable between three configurations in which:
characterized in that the inner member is adapted to be sealed to the outer member when in at least one of configurations i) and ii) but is arranged to be clear of at least a portion of the outer member when in configuration iii).
Preferably, the telescoping device comprises a seal member provided on one of the inner and outer members wherein the seal acts against the other of the inner and outer members to thereby provide a seal therebetween when the telescoping device is in at least one of the configurations i) and ii). Preferably, the seal member is provided on one of the inner and outer members in such a manner that the seal is clear of the at least a portion of the other of the inner and outer members to thereby not make contact with and thereby not provide a seal with the other of the inner and outer members when the telescoping device is in configuration iii).
Preferably, the telescoping device comprises a selective locking system to selectively lock the inner member to the said outer member. Typically, the locking system comprises a dog member provided on one of the inner and outer members and which is preferably moveable toward and away from the other of the inner and outer members to make contact with the other of the inner and outer members to prevent relative movement occurring therebetween.
Preferably, the dog member is provided on the outer member and is preferably selectively moveable toward and away from the inner member to make contact with an outer portion of the inner member to prevent relative movement occurring therebetween. Typically, the outer portion of the inner member comprises a formation formed at least part way around the outer circumference of the inner member. Preferably, the inner member comprises two said formations at or toward each end of the inner member.
Typically, one of the inner and outer members is provided with a varied inner or outer circumference such that the seal is prevented from acting against the other of the inner and outer members when the seal is at a location in between the said two formations such that the seal does not act when the telescoping device is in configuration iii).
Typically, the seal is mounted on a portion secured to the outer member and acts against an inner bore of the inner member. Typically, the seal is located within the bore of the inner member and acts against the inner surface of the bore of the inner member. Typically, the seal is secured within a recess provided on an outer surface of the said portion secured to the outer member and acts against the inner surface of the bore of the inner member to provide a seal therebetween when the telescoping device is in one of configurations i) or ii).
Preferably, the dog member is moved radially towards or away from the said respective formation by an actuating mechanism which preferably comprises at least one angled or tapered surface provided on the dog member and against which the actuating mechanism acts upon in a direction substantially parallel to the longitudinal axis of the riser system and which results in movement of the dog member in a direction substantially perpendicular to the longitudinal axis of the riser system.
Preferably, the riser system is provided with one or more in-line valves which may be selectively opened or closed to respectively permit or prevent flow of fluid through the throughbore of the riser system. Preferably, at least one of said in-line valves is located below the valved tree member when the one or more valves of the valved tree member are in sealed fluid communication with the throughbore of the riser system and more preferably, at least one and typically two in-line valves are located between the valved tree member and the telescoping device. Typically, the telescoping device is located vertically above the two inline valves which in turn are located vertically above the flow diverter member and which in turn is located vertically above at least one in-line valve.
According to a third aspect of the present invention there is provided a riser completion system comprising:
a riser system comprising a lower in-line valve, a flow diverter member located above the lower inline valve and at least one upper in-line valve located above the flow diverter member and a telescoping device located above the said upper in-line valve to permit compensation for heave; and
a valved tree member suitable for use in the region of a moon pool on a floating vessel, the valved tree member comprising:
Typically, the flow diverter member comprises:
According to the present invention there is further provided a method of completing a riser installation comprising the steps of:
i) lowering a riser system from a vessel at the surface of a body of water to or in close proximity to the surface at the bottom of the body of water;
ii) connecting a lower inline valve toward an upper end of the riser system;
iii) connecting a flow diverter member above the said lower inline valve in the riser system;
iv) connecting at least one upper inline valve above the said flow diverter member in the riser system;
v) connecting a telescoping member above the said upper inline valve in the riser system;
vi) connecting the lower end of the riser system to wellhead equipment provided at the head of a well;
vii) providing a valved tree member suitable for use in the region of a moon pool on the vessel, the valved tree member comprising one or more valve members adapted to selectively permit and prevent flow of fluid therethrough, and one or more moveable stab members wherein the riser system is run into the sea through a throughbore of the valved tree member;
viii) aligning the T-piece with the valved tree member and coupling the flow diverter member and moving the said one or more stab members to respectively seal with at least one portion of the flow diverter member to thereby provide a sealed fluid communication path between a throughbore of the riser system and the one or more valve members;
wherein the flow of fluid produced from the upper end of the riser system is capable of being selectively diverted from flowing up through the upper end of the riser system and instead is capable of being selectively diverted through the said one of more stab members and through the said one or more valves of the valved tree member.
In the description that follows, like parts are marked throughout the specification and drawings with the same reference numerals, respectively. The drawings are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form, and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present invention is susceptible to embodiments of different forms. There are shown in the drawings, and herein will be described in detail, specific embodiments of the present invention with the understanding that the present disclosure is to be considered an exemplification of the principles of the invention, and is not intended to limit the invention to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce the desired results.
The following definitions will be followed in the specification. As used herein, the term “riser” refers to a riser string coupled to a wellhead at the head of a wellbore or borehole being provided or drilled in a manner known to those skilled in the art. Reference to up or down will be made for purposes of description with the terms “above”, “up”, “upward”, “upper”, or “upstream” meaning away from the bottom of the body of water along the longitudinal axis of the riser toward the surface of the body of water and “below”, “down”, “downward”, “lower”, or “downstream” meaning toward the bottom of the body of water along the longitudinal axis of the riser and away from the surface and deeper into the body of water toward the wellhead.
The various aspects of the present invention can be practiced alone or in combination with one or more of the other aspects, as will be appreciated by those skilled in the relevant arts. The various aspects of the invention can optionally be provided in combination with one or more of the optional features of the other aspects of the invention. Also, optional features described in relation to one embodiment can typically be combined alone or together with other features in different embodiments of the invention. Additionally, any feature disclosed in the specification can be combined alone or collectively with other features in the specification to form an invention.
Various embodiments and aspects of the invention will now be described in detail with reference to the accompanying figures. Still other aspects, features, and advantages of the present invention are readily apparent from the entire description thereof, including the figures, which illustrates a number of exemplary embodiments and aspects and implementations. The invention is also capable of other and different embodiments and aspects, and its several details can be modified in various respects, all without departing from the spirit and scope of the present invention.
Any discussion of documents, acts, materials, devices, articles and the like is included in the specification solely for the purpose of providing a context for the present invention. It is not suggested or represented that any or all of these matters formed part of the prior art base or were common general knowledge in the field relevant to the present invention.
Accordingly, the drawings and descriptions are to be regarded as illustrative in nature, and not as restrictive. Furthermore, the terminology and phraseology used herein is solely used for descriptive purposes and should not be construed as limiting in scope. Language such as “including”, “comprising”, “having”, “containing” or “involving” and variations thereof, is intended to be broad and encompass the subject matter listed thereafter, equivalents, and additional subject matter not recited, and is not intended to exclude other additives, components, integers or steps. In this disclosure, whenever a composition, an element or a group of elements is preceded with the transitional phrase “comprising”, it is understood that we also contemplate the same composition, element or group of elements with transitional phrases “consisting essentially of”, “consisting”, “selected from the group of consisting of”, “including”, or “is” preceding the recitation of the composition, element or group of elements and vice versa. In this disclosure, the words “typically” or “optionally” are to be understood as being intended to indicate optional or non-essential features of the invention which are present in certain examples but which can be omitted in others without departing from the scope of the invention.
All numerical values in this disclosure are understood as being modified by “about”. All singular forms of elements, or any other components described herein including (without limitations) components of the riser system are understood to include plural forms thereof and vice versa.
Embodiments of the present invention will now be described, by way of example only, with reference to the accompanying drawings, in which:
As can be seen in
The riser system 35 further comprises a riser string 32 and a riser running tool 30, where the upper end of the EDP 22 is picked up by running the riser running tool 30 being provided at the lower end of the string 32 of flexible riser pipe 32T connected end 32P to end 32B by suitable connections such as a Merlin™ connection offered by Oil States Industries (UK) Limited of Aberdeen, UK (only a very short portion of the riser string 32 is shown in
The next stage of installation of the riser system 35 as can be seen in
As can be seen in
Additional lengths of flexible riser tubing 32T continue to be made up by the make up tool 40 into the riser string 32 at the upper end thereof such that the LRP 24 and EDP 22 continue to be lowered on the riser string 32 down toward the christmas tree 20 as shown in
The combined landing ring and flow diverter piece 66 preferably comprises a vertically arranged main body in the form of a tubular or pipe 66 having an upper 66U and a lower 66L half connected into the riser string 32 and forming part of it and having its longitudinal throughbore 33, where the upper half 66U and lower half 66L are formed integral with or are securely and sealingly coupled to a landing ring 65 and which has a lower shoulder 72 formed or provided around its outer lower most circumference (the use of which will be detailed subsequently) and which also comprises a horizontally arranged throughbore 67 which perpendicularly intersects the main vertically arranged longitudinal throughbore 33 and through which produced fluids from the subsea well can be diverted through into stabs 76A, 76B when connected thereto (as will be described subsequently). A key (not shown) and groove (not shown) are provided to ensure the correct rotational alignment occurs between the combined landing ring and flow diverter 66 and more particularly between the throughbore 67 and the stabs 76A, 76B during seating of the landing ring 66 against an upwardly directed shoulder 74 (as will be described in more detail subsequently). The skilled reader will understand that the annular ring shaped landing ring 65 with a horizontally arranged cross intersecting throughbore 67 could be replaced by a pair of laterally arranged tubular output ports which provide the same horizontally arranged cross intersecting throughbore 67 but the annular ring shaped landing ring 65 has the advantage of spreading the seating load 360° around its whole circumference due to the seating contact between the respective shoulders 72 and 74 as will be described in more detail subsequently.
As can be seen in
However, just prior to the moment when the upper riser package 48 starts passing through the bore 51 of the moon pool surface tree 50, the upper set of dogs 52U are retracted from their recess in the diverter housing 42 such that the upper dogs 52U are released from the diverter housing 42 and therefore the moon pool surface tree 50 is disconnected from the diverter housing 42. Instead, the weight of the ASR 44 and thus the moon pool surface tree 50 is taken up by at least two and preferably at least three (not shown) tension wires 82A, 82B which are payed out from respective tension wire reels 84A, 84B secured to the vessel 8 and this stage of the riser installation method is shown in
The weight of the moon pool surface tree 50 is thus taken up by the ASR 44 and thus the tension wire reels 84A, 84B and the moon pool surface tree 50 and ASR 44 are lowered a short distance away from the lower end of the diverter housing 42. The upper riser package 48 is then lowered through the diverter housing 42 and through the bore 51 of the moon pool surface tree 50 until a lower shoulder 72 of the combined landing ring/flow diverter piece 66 makes contact with and therefore butts against an upwardly directed shoulder 74 provided around the inner bore 51 of the moon pool surface tree 50 such that at least a proportion of and possibly up to the whole weight of the riser string is taken on the upwardly directed load shoulder 74 and therefore by the tension wires 82A, 82B and the tension wire reel 84A, 84B and at this point the riser string is in the running in configuration shown in
The LRP 24 is secured to the tree cap 28 and then the combined landing ring/flow diverter piece 66 and thus the rest of the upper riser package 48 and the riser string 32 indeed the whole riser system 35 can be secured to the moon pool surface tree 50 by actuating stabs 76A, 76B located within laterally arranged flanged pipes 90A, 90B mounted horizontally on each side of the moon pool surface tree 50 such that the throughbores of the flanged pipes 90A, 90B are horizontally aligned with one another and are arranged perpendicularly to the longitudinal and vertically arranged throughbore 51 of the moon pool surface tree 50. The stabs 76A, 76B are arranged such that they can be actuated to move radially inwardly (with respect to the longitudinal vertically arranged throughbore 51) from being wholly located within the throughbore of the flanged pipes 90A, 90B to respectively project at least partially into the horizontally arranged throughbore 67 of the laterally projecting side ports 69A, 69B of the combined landing ring/flow diverter piece 66. The radially inner most ends of the stabs 76A, 76B are provided with suitable seals such as O-ring seals 78A, 78B around their outer circumference such that the respective throughbore 76AT; 76BT of the stabs 76A, 76B is sealed by the seals 78A, 78B with respect to the throughbore 67 of the combined landing ring/flow diverter piece 66. Accordingly, the stabs 76A, 76B have a dual function of not only physically locking the combined landing ring/flow diverter piece 66 and thus the riser string 32 to the moon pool surface tree 50 but also provide a seal between:
At this point the operator now has the option of diverting fluid located in or flowing through the throughbore 33 of the riser string 32 located below the middle ball valve 64 out of the throughbore 33, through the throughbore 76B and through the lateral ball valves 70A, 70B located on the moon pool surface tree 50 and out of lateral exit ports 71A, 71B into e.g. conduits or hoses (not shown) and onto further pressurized fluid containment equipment (not shown) which may be located below the drill floor 12 by ensuring that upper ball valve 62 and middle ball valve 64 are closed such that fluid cannot flow through the throughbore 33 up through the middle ball valve 64 or upper ball valve 62. It should be noted that only one upper or middle ball valve 62, 64 is required but two are provided to ensure that there is redundancy in case one is stuck or malfunctions and cannot close. Accordingly, the operator can conduct a well test via the lateral ball valves 70A, 70B of the moonpool surface tree 50.
Consequently, the moon pool surface tree 50 provides the great advantage that, in combination with the combined landing ring/flow diverter piece 66, and the valves 62, 64, 68 run therewith, the potentially highly pressurized fluid such as produced hydrocarbons located within the throughbore 33 below the moon pool surface tree 50 can be safely controlled, thus allowing the operator to perform a well test or conduct work on the riser system 35 and/or riser string 32 located above the moon pool surface tree 50 and more particularly located above the upper ball valve 62. For example, the final required equipment 100, 102, 104 can be safely installed to the upper end of the universal connection 61 provided at the uppermost end of the telescopic joint 60 in a safe manner because the pressurized fluid located within the throughbore 33 is all located below the closed upper 62 and middle 64 ball valves and is being safely diverted to said other pressurized fluid containment equipment.
However, to further increase the safety of connecting that final safety equipment such as a surface tree 100, lubricator 102 and/or coiled tubing unit 104, the telescopic joint 60 is adapted to be able to stroke out from the fully stroked in (also referred to as the running in configuration) configuration shown in
The telescopic joint 60 in accordance with the second aspect of the present invention comprises an outer barrel 110 which is secured at its lower end 110L to the upper end of the upper ball valve 62 such that the throughbore 109 of the telescopic joint 60 is in sealed fluid communication with the throughbore 33 of the riser string 32 and the rest of the riser system 35 (assuming that the upper 62 and middle 64 in-line ball joints are open). The inner bore 109 comprises a protruding tubular end 111 which projects upwardly and to which is secured (by means of a suitable fixing means such as welding or a sealed screw thread or other suitable fixing means) to the lower end of an internal sealing tube 115 at its lower end 115L. It should be noted that the internal sealing tube 115 is preferably a separate component from the rest of the outer barrel 110 to aid manufacture and installation and also to aid repair but it could be that the internal sealing tube 115 is a one piece unit integral with the outer barrel 110. The outer diameter of the internal sealing tube 115 forms an annulus 116 with the inner bore of the rest of the outer barrel 110 and an inner barrel 120 is located in that annulus 116 (when in the fully stroked in configuration as shown in
The inner barrel 120 is provided with a formation in the form of an upper dog ring 126U provided towards its upper end on its outer surface and is further provided with a lower dog ring 126L provided toward or at its lower end again on its outer surface. Two or more concentrically spaced apart dogs 124 are provided around the outer circumference of the inner barrel 120 and are located in a suitably sized recess within the outer barrel 110 where the dogs 124 can be forced radially inwardly toward the outer surface of the inner barrel 120 by means of a cam ring 128 which can be forced (when actuated to do so by actuating cylinders 130) in a downwards direction to act on a tapered outer face 124T of the dogs 124 to force the dogs 124 radially inwardly against the outer surface of the inner barrel 120 and in particular to trap the upper dog ring 126U or lower dog ring 126L as appropriate within a recess 124R formed on the inner surface of the dogs 124.
Consequently, when the respective dog ring 126U, 126L is trapped within the recess 124R, the inner barrel 120 is locked with respect to the outer barrel 110. Moreover, when the upper dog ring 126U is trapped within the recess 124R (as shown in
When the operator decides to allow the inner barrel 120 to stroke out of the inner barrel 110, he actuates the cylinders 130 to move the cam ring 128 upwards which in turn permits the dogs 124 to relax or move radially outwardly away from the upper dog ring 126U such that the inner barrel 120 can now move upwards with respect to the outer barrel 110 as shown in
Importantly, the inner bore of the inner barrel 120 is provided with a slightly enlarged inner bore 121 along its upper and its middle section such that the slightly enlarged inner bore 121 clears the pair of seals 117 such that the slightly enlarged inner bore 121 is not sealed with respect to the outer surface of the internal sealing tube 115 and in use, this has the advantage that the seals 117 will not be worn away by the telescoping action of the inner barrel 120 moving with respect to the internal sealing tube 115 and the outer barrel 110. Because of this feature, the operator will ensure that when the inner barrel 120 is in the closed or fully stroked in configuration shown in
The telescopic joint 60 is shown in the fully stroked out or fully open position in
The hydraulic valve stabs 140 provide a suitable connection such as to supply electrical power or supply of pneumatic or hydraulic fluid to the various ball valves 62, 64, 68, 70 and also provide for hydraulic connection for operation of the actuating cylinders 130 such that electric power and/or hydraulic fluid can be delivered to the various valves 62, 64, 68, 70 and also the actuating cylinder 130 to operate the respective valves 62, 64, 68, 70 and/or the telescopic joint locking/unlocking system and therefore all power and/or hydraulic supplies to the various valves 62, 64, 68, 70 and the actuating cylinder 130 can be connected up before the equipment is run and this eliminates the need for man-riding during set up thereby greatly improving safety. Only two hydraulic valve stabs 140 are shown in
Accordingly, embodiments of the present invention described herein provide the ability to remotely operate the various valves 62, 64, 68, 70 and/or the actuating cylinder 130 (the remote operation possibly being conducted a relatively short or a relatively long distance away from the relevant equipment 62, 64, 68, 70, 130 either on or off the vessel 8) and also provide the advantage of permitting remote disconnection of the equipment on the drill floor 12 to the riser system 35 and also provide the great advantage of allowing for the halting or the diversion of production flow to relevant equipment on or below the drill floor 12.
These advantages individually or combine to permit work to be safely carried out on the top level equipment 100, 102, 104 on the drill floor without the hazards associated with sea movement.
Consequently, the various embodiments described herein provide numerous significant safety and operational advantages over conventional riser systems.
Modifications or improvements may be made to the embodiments described herein without departing from the scope of the invention.
| Number | Date | Country | Kind |
|---|---|---|---|
| 1503844.1 | Mar 2015 | GB | national |
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/GB2016/050548 | 3/2/2016 | WO | 00 |
