Patent Grant
11982161
The present invention relates to apparatus, systems and methods for oil and gas operations, in particular to apparatus, systems and methods for providing fluid control, and/or performing measurement and/or intervention in oil and gas production or injection systems. The invention has particular application to subsea oil and gas operations, and aspects of the invention relate specifically to apparatus, systems and methods for fluid control, measurement and/or intervention in subsea oil and gas manifolds, in particular, in subsea in-line tees.
In the field of subsea engineering for the hydrocarbon production industry, it is known to provide flow systems comprising manifolds. A subsea manifold may be connected to one or more flowlines coming from or going to other flow infrastructure within the flow system.
One type of subsea manifold is a well gathering manifold. This can accommodate numerous subsea wells at once and often also has additional functionality. An alternative type of subsea manifold is an in-line tee. An in-line tee is a piece of infrastructure which can be incorporated into a pipeline or a flowline to create a branched tie-in point for an additional pipeline or flowline. For example, an in-line tee may provide a tie-in point to a main production flowline for a flowline carrying production fluids from a subsea well.
The term “subsea manifold” may also be used more generally to refer to a subsea well gathering system. A subsea well gathering system is a subsea flow system into which production flow from one or more subsea wells is directed or which has the capacity to receive production flow from one or more subsea wells.
During the development of subsea hydrocarbon fields, it is often the case that new hydrocarbon discoveries are made and/or further tie-ins to the flow system infrastructure are required. As such, one or more in-line tees may be provided on the flow system to accommodate future tie-in requirements. If an in-line tee tie-in point is not immediately required, the branched tie-in point may be provided with a flow cap to shut it off, such that the pipeline can function as normal until such time that the tie-in point is required.
Providing in-line tees on the flow system to meet current and future well tie-in requirements will bring initial expenditure down, because in-line tees are generally less expensive than the typical well-gathering manifolds that can accommodate numerous wells at once. However, a collection of numerous in-line tees can function in the same manner as a conventional well gathering manifold, but instead distributed over a pipeline system. They therefore provide a distributed manifold system which can be selectively populated and utilised as and when project requirements demand. This can also lead to cost savings in the future. For example, reduced drilling costs because the top-hole can be drilled in an optimal position and served by one of several in-line tees; whereas typically, top-hole location is influenced by the fixed location of existing subsea infrastructure.
In-line tees are fully equipped with the equipment, instrumentation and valving needed to facilitate the tie-in and production of one or more the future wells. Whatever the type of subsea manifold, if the internal equipment, instrumentation and/or valving within the manifold is to fail, in order to repair or replace these parts the entire manifold must be recovered. This typically requires large vessels, is expensive, disruptive and potentially damaging to the surrounding subsea infrastructure, and disruptive to production operations.
It is amongst the aims and objects of the invention to provide a subsea in-line tee arrangement and method of use which mitigates drawbacks of prior art subsea in-line tees and methods of use.
It is amongst the aims and objects of the invention to provide an apparatus, system and a method of use for providing fluid control, fluid measurement and/or intervention in a flow system of an oil and gas production installation—for example, in a subsea manifold such as an in-line tee—which is an alternative to the apparatus and methods described in the prior art.
It is amongst the aims and objects of the invention to provide an apparatus, system and a method of use for providing fluid control, fluid measurement and/or intervention in an oil and gas production installation, which addresses one or more drawbacks of the prior art.
An object of the invention is to provide a flexible apparatus, system and method of use suitable for use with and/or retrofitting to industry standard or proprietary oil and gas system infrastructure including subsea manifolds, and in particular in-line tees.
Further objects and aims of the invention will become apparent from the following description.
According to a first aspect of the invention, there is provided a subsea in-line tee arrangement configured to be located in a subsea production pipeline of a subsea production system, the subsea in-line tee arrangement comprising:
The in-line tee may comprise an isolation valve.
The removable module may comprise an isolation valve.
The removable module may be configured to be assembled with a flowline jumper and may be configured to provide flow access between a jumper flowline and the subsea in-line tee. The removable module may be configured to provide direct flow access between a jumper flowline and the in-line tee via one or more flow paths in the removable module. Alternatively, or in addition, the removable module may be configured to provide flow access between a jumper flowline and the in-line tee via one or more process apparatus connected to the interface of the removable module.
The in-line tee may comprise a main body. The in-line-tee may comprise first and second connectors and may define a main flow path between the first and second connectors. The first and second connectors may be an inlet and an outlet for production flow from a main production flowline system, respectively, and may be configured to integrate the in-line tee into a pipeline. The main flow path of the in-line tee is may be continuous with the pipeline.
The in-line tee may further define one or more branched flow paths which may each be in fluid communication with the main flow path and one or more further connectors of the in-line tee. The one or more further connectors may define one or more branched tie-in points. The at least one connector of the removable module may be configured to be connected to a branched tie-in point of the in-line tee.
The interface may be configured to receive a process apparatus, or multiple process apparatus.
The removable module may be a flow access apparatus or a flow access hub, which may be configured to enable flow access to the subsea pipeline via the in-line tee.
The at least one connector of the removable module for connecting the module to the in-line tee may be a first connector. The flow path defined between the at least one connector (in other words, the first connector) and the interface may be a first flow path. The first flow path may comprise an isolation valve. The interface may be a single bore interface
The removable module may further comprise a second connector. The second connector may be for connecting the module to a flowline, such as a jumper flowline. The removable module may be a part of a flowline jumper system, and therefore may be within the jumper envelope. The removable module may therefore be a flow access apparatus or flow access hub that can be deployed with the jumper system and/or retrieved from the in-line tee and subsea flow system with the jumper system, without causing disruption to the in-line tee or the wider flow system. The second connector may be configured to receive production fluid from a subsea well. The removable module may further define a second flow path between the second connector and the interface. The second flow path may comprise an isolation valve. The interface may be a dual bore interface.
Alternatively, the interface may be a multi-bore interface.
The removable module may comprise one or more control lines, which may be hydraulic, electrical and/or fibreoptic control lines. The removable module may comprise a control interface, which may include connection points for the one or more control lines. The control interface may be configured to connect to a similar control interface of a process apparatus. The one or more control lines may be connected to, and supplied from, an umbilical. The one or more control lines may be affixed to the removable module, or may be integrated internally.
The process apparatus may be a functional module, and may be configured to perform one or more functions selected from the group comprising: fluid control, fluid sampling, fluid diversion, fluid recovery, fluid injection, fluid circulation, fluid access, fluid measurement, flow measurement and/or fluid metering. The removable module may comprise a flow loop.
The process apparatus may be configured to perform one or more functions selected from the group comprising: fluid control, fluid sampling, fluid diversion, fluid recovery, fluid injection, fluid circulation, fluid access, fluid measurement, flow measurement and/or fluid metering. The process apparatus may comprise a flow loop.
The process apparatus may comprise a choke valve, which may be a production choke valve.
The term fluid encompasses references to liquid and/or gas and/or a combination.
According to a second aspect of the invention, there is provided a subsea in-line tee arrangement configured to be located in a subsea production pipeline of a subsea production system, the subsea in-line tee arrangement comprising:
The subsea in-line tee may comprise an isolation valve.
Where the subsea in-line tee comprises an isolation valve, the process apparatus may be configured to provide control to the isolation valve. The process apparatus may be connected to control lines which may be from a subsea umbilical. The control lines of the process apparatus may be connected to the isolation-valve of the in-line tee. The control lines may be electrical, hydraulic,
The process apparatus may comprise a flow loop.
The process apparatus may comprise a choke valve, which may be a production choke valve.
Embodiments of the second aspect of the invention may include one or more features of the first aspect of the invention or its embodiments, or vice versa.
According to a third aspect of the invention, there is provided a subsea in-line tee configured for connection to a subsea production system, the subsea in-line tee comprising:
The subsea production pipeline may carry production flow from one or more subsea wells.
The subsea in-line tee may be configured to receive production fluid from one or more additional subsea wells. The subsea in-line tee may be configured to route the production fluid from one or more additional subsea wells into the subsea production pipeline, such that the production flow from one or more subsea wells and the production fluid from one or more additional subsea wells is commingled and flows together.
Preferably, the in-line tee is welded into a subsea production pipeline of the subsea production flow system, such that the in-line tee is integrated into the pipeline.
The in-line tee may further comprise a valve positioned in the branched flow path. The valve may be an isolation valve.
The in-line tee may be connected to a removable module directly, or via a flowline such as a jumper flowline.
The in-line tee may be connected to a process apparatus directly, or via a flowline such as a jumper flowline.
Alternatively, the in-line tee may be connected to a subsea Christmas tree, a subsea manifold or one or more subsea wells via one or more flowlines.
Embodiments of the third aspect of the invention may include one or more features of the first or second aspects of the invention or their embodiments, or vice versa.
According to a fourth aspect of the invention there is provided a removable module for a subsea in-line tee of a subsea production system, the removable module comprising: at least one connector configured to connect the module to the subsea in-line tee; and an interface for connecting the module to the at least one process apparatus.
The removable module may be a flow access apparatus or a flow access hub, which may be configured to enable flow access to the subsea pipeline via the in-line tee.
Optionally, the removable module may also be configured to perform one or more functions selected from the group comprising: fluid control, fluid sampling, fluid diversion, fluid recovery, fluid injection, fluid circulation, fluid access, fluid measurement, flow measurement and/or fluid metering. The removable module may comprise a flow loop.
The removable module may define a flow path between the at least one connector and the interface. The at least one connector of the removable module for connecting the module to the in-line tee may be a first connector, and the flow path defined between the at least one connector (in other words, the first connector) and the interface may be a first flow path. The interface may be a single bore interface.
The removable module may further comprise a second connector. The second connector may be for connecting the module to a flowline, such as a jumper flowline. The second connector may be configured to receive production fluid from a subsea well. The removable module may further define a second flow path between the second connector and the interface. The second flow path may comprise an isolation valve. The interface may be a dual bore interface.
Alternatively, the interface may be a multi-bore interface.
The removable module may be a part of a flowline jumper system, and therefore may be within the jumper envelope. The removable module may therefore be a flow access apparatus or flow access hub that can be deployed with the jumper system and/or retrieved from the in-line tee and subsea flow system with the jumper system, without causing disruption to the in-line tee or the wider flow system.
Embodiments of the fourth aspect of the invention may include one or more features of the first to third aspects of the invention or their embodiments, or vice versa.
According to a fifth aspect of the invention, there is provided a subsea oil and gas production installation, the installation comprising:
The removable module may be a flow access apparatus or a flow access hub, which may be configured to enable flow access to the subsea pipeline via the in-line tee.
The removable module may be a part of a flowline jumper system, and therefore may be within the jumper envelope. The removable module may therefore be a flow access apparatus or flow access hub that can be deployed with the jumper system and/or retrieved from the in-line tee and subsea flow system with the jumper system, without causing disruption to the in-line tee or the wider flow system.
Embodiments of the fifth aspect of the invention may include one or more features of the first to fourth aspects of the invention or their embodiments, or vice versa.
According to a sixth aspect of the invention, there is provided a method of installing a removable module to a pre-installed subsea in-line tee, the method comprising:
The removable module may be a part of a flowline jumper system, and therefore may be within the jumper envelope. The removable module may therefore be a flow access apparatus or flow access hub that can be deployed with and/or retrieved from the in-line tee and subsea flow system without causing disruption to the in-line tee or the wider flow system.
The method may comprise deploying the removable module subsea.
The subsea in-line tee may be integrated into and/or located in a subsea production pipeline.
The connector of the in-line tee may be connected to a pre-installed flow component. The method may comprise removing the pre-installed flow component from the connector of subsea in-line tee before the removable module is coupled to the in-line tee.
The pre-installed flow component may be a flow cap, a flowline, a flow module, a processing apparatus or alternative piece of equipment.
The at least one connector may be a first connector and the removable module may comprise a second connector which may be coupled to a jumper flowline and forming a jumper flowline and removable module assembly.
The method may comprise coupling the removable module and jumper flowline assembly to the connector of the subsea in-line tee.
The removable module may further comprise an interface which may be fluidly connected by at least one flow path to the first connector. The method may comprise connecting a process apparatus to the interface of the removable module.
Embodiments of the sixth aspect of the invention may include one or more features of the first to fifth aspects of the invention or their embodiments, or vice versa.
According to a seventh aspect of the invention, there is provided a method of installing a process apparatus to a pre-installed subsea in-line tee, the method comprising:
Embodiments of the seventh aspect of the invention may include one or more features of the first to sixth aspects of the invention or their embodiments, or vice versa.
According to an eighth aspect of the invention, there is provided a subsea production pipeline, the pipeline comprising:
Embodiments of the eighth aspect of the invention may include one or more features of the first to seventh aspects of the invention or their embodiments, or vice versa.
According to a ninth aspect of the invention there is provided a subsea in-line tee arrangement for a subsea production flow system, the subsea in-line tee arrangement comprising:
The subsea in-line tee may be integrated into the pipeline at a position adjacent the base of a production riser. Alternatively, the subsea in-line tee may be configured to be coupled directly to the base of a production riser.
The in-line tee may comprise a main flow path which may be continuous with the production flowline into which it is integrated. The in-line tee may further comprise a branched flow path, which may be defined between the main flow path and a connector on the in-line tee. The at least one connector on the removable module may be removably connected to the connector on the in-line tee.
The gas lift apparatus may comprise an inlet for connection to one or more gas lift delivery lines. The gas lift apparatus may comprise an outlet connector. The outlet connector may be fluidly connected to the interface of the removable module. The gas lift apparatus may comprise a main flow bore, which may be defined between the inlet and the outlet connector and which may fluidly connect the inlet and the outlet connector. The main flow bore may comprise an injection check valve. The main flow bore may comprise an injection nozzle which may function to control injection of gas from the delivery line into the main flow path of the in-line tee. The main flow bore may comprise a valve which controls the inlet of gas into the flow system. The valve may be hydraulically actuated and may be contacted to an umbilical which may provide hydraulic control.
The gas lift apparatus may comprise a pressure and/or temperature transducer.
The removable module may be a part of a flowline jumper system, and therefore may be within the jumper envelope. The removable module may therefore be a flow access apparatus or flow access hub that can be deployed with and/or retrieved from the in-line tee and subsea flow system without causing disruption to the in-line tee or the wider flow system.
Embodiments of the ninth aspect of the invention may include one or more features of the first to eighth aspects of the invention or their embodiments, or vice versa.
According to a tenth aspect of the invention there is provided a method of performing a gas lift operation in a subsea flow system, the method comprising:
Embodiments of the tenth aspect of the invention may include one or more features of the first to ninth aspects of the invention or their embodiments, or vice versa.
There will now be described, by way of example only, various embodiments of the invention with reference to the drawings, of which:
Referring firstly to
Typical subsea in-line tees, like the kind shown in
In-line tees are subject to particularly strict size and weight constraints because they are assembled into the pipeline or sections of the pipeline (often by welding, although other connection methods may be used) prior to its installation subsea. Installation may be by any conventional, known pipe-lay methods including: S-lay, J-lay and reel-lay methods. What all of these pipe-lay methods have in common is that the assembled pipeline must be lowered from the pipe-lay vessel at sea level to the seabed. Therefore, the overall size and shape of an in-line tee must be restricted in order to allow it to be handled by conventional pipe-lay equipment such as tensioners. Additionally, the weight of an in-line tee must be constrained because this weight will act on the pipeline as it is lowered subsea.
For example, with reference to
Referring now to
The in-line tee 214 is a simplified in-line tee and comprises a main body 222, which defines a main flow through path 225 between connectors 224 and 226 (i.e. an inlet and an outlet). Connectors 224 and 226 integrate the in-line tee into a pipeline 212 (only part of which is shown in
The main flow path 225 of the in-line tee is continuous with the pipeline 212. The in-line tee 214 also defines a branched flow path 227 (see
A flow cap can be placed over the branched tie-in point 216 such that the tee 214 merely functions as an extension of the pipeline 212. This may be done, for example, when future field expansion is anticipated in order to provide a tie-in point for an additional subsea well that is expected to be required in the future. Although not shown in
For clarity, in the schematic view of
The flowline 238 is a jumper flowline, and the module 228 facilitates the connection of the jumper flow line 238 to the main production bore 212 via the relatively large bore size of the tie-in point of the in-line tee. The removable module 228 provides a convenient location to connect a jumper flowline to the tee to provide flexibility in field development and production by providing a flowline connector for a jumper flowline where one did not previously exist. Furthermore, by providing a removable module as part of the flowline jumper system, in the flowline jumper envelope, the module 228, the jumper 238 and any process apparatus or apparatuses connected to the module, are detachable and retrievable from the main production flow system incorporating the in-line tee.
The module 228 provides a convenient single interface 236 for one or more removable and/or retrievable process apparatus to be landed on the module 228. The module 228 is therefore a convenient means for providing the simplified in-line tee with access to equipment incorporating the valves, piping components, sensors and/or other functional elements and instrumentation required to provide the necessary flow control and flow monitoring functions required by the in-line tee, all whilst preserving the original capability of the in-line tee to receive fluids from an additional flowline (such as an additional subsea well) via the branched tie-in point. The module 228 is also operable to provide access via its interface 236 to equipment which may provide the in-line tee with additional functionality, such as flow processing and intervention equipment.
The module 228 protects the in-line tee from damage that may be caused by impacts during connecting or disconnecting various process apparatus and/or flowlines to the system, and/or from ongoing loads from these components following their installation. This is a benefit of the module 228. As the module 228 is provided within the jumper envelope (i.e. in the flowline jumper system) its retrieval and replacement, for example if damaged, is a substantially more cost-effective, simpler and less disruptive procedure than replacement or repair of the in-line tee, and does not require production shut down from upstream production wells.
In the embodiment shown in
In the embodiment shown in
By providing an in-line tee arrangement 210 comprising a simplified, stripped back in-line tee 214 and a removable module 228, a number of benefits are realised. Such benefits include a reduction in size of the in-line tee, a reduction in weight of the in-line tee and the optional ability to provide improved functionality to the in-line tee.
By removing the valves, piping components and sensors which are incorporated into a typical subsea in-line tee structure, a passive, simplified in-line tee structure which facilitates flow through in the usual manner is provided, which facilitates an optional additional tie-in point for a future subsea well (or other such flowline). Initial project expenditure is reduced by the ability to provide a simplified in-line tee only, having the option of adding greater future functionality by using a removable module and one or more process apparatus in the future, if required.
The cost-effective nature of the simplified in-line tees enables a greater number of multiple in-line tees to be provided in a pipeline. This facilitates the creation of multiple tie-in and/or flow access points for future use, with minimal disruption to the pipeline and additional flow infrastructure. When used to tie-in subsea wells and/or provide other flow access functions, a bundle of in-line tees can function like a conventional well gathering manifold, distributed over a pipeline system. They provide a distributed manifold which can be selectively populated and utilised as and when project requirements demand.
By integrating simplified in-line tees into the main flowline, with removable and process modules provided within a jumper flowline envelope system, all active components are made retrievable. In addition, the retrievable nature of the module 228 and the one or more process apparatus 240 means that they can be retrieved and replaced without disturbing the in-line tee itself, the main production flowline into which the in-line tee is integrated or yet further subsea infrastructure. It also facilitates a change in purpose or functionality and provides the flexibility to integrate emerging technologies into the flow system as and when they are developed in the future, which could aid with reservoir management and increased recovery.
The in-line tees are installed by pipe-lay vessel, and the removable modules are installed when they are required by RSV work vessel, or any other suitable vessel. This eliminates the requirement for heavy lift vessel mobilisation for subsea field construction. The removable modules can be subsequently retrieved and/or changed by a field work vessel.
In-line tee arrangements provided with alternative process apparatus are shown in
The installation and connection of an in-line tee arrangement subsea will now be described with reference to
As described above, in-line tees are typically assembled into a pipeline (or sections of pipeline) prior to its installation subsea.
When installation of the pipeline 612 is complete, and confirmation is given that the in-line tees 614 are in their correct positions, the mud mats 654 can be folded out, as shown in
When it is time to connect a subsea well to an in-line tee, a removable module 628 and jumper flowline 658 assembly is deployed subsea. Locating the removable module 628 as part of the flowline jumper system (in the jumper flowline envelope) in this way provides a mechanism for the jumper flowline 658 to connect to the in-line tee and thus the flow system. The removable module is connected to the upper connector of the in-line tee 614 following deployment, and is initially provided with a flow cap or a flow loop apparatus (not shown) mounted thereon. As is shown in
If the removable module 628 is provided with a simple flow loop apparatus on its interface, the production fluid from the tree 656 is able to join that in the main production pipeline 612 via the in-line tee 614 and the jumper flowline and removable module 628 assembly, provided any valves within removable module 628 and/or the in-line tee 614 are open.
Although the foregoing description concerns the use of dual bore removable modules, which consequently provide a dual bore interface, it will be appreciated that the removable module may alternatively be a single or a multi bore module.
For example,
This embodiment also differs from those previously described in that the interface of the removable module is not connected to a process apparatus. Instead, the single bore interface 736 is connected to a further jumper flowline 739 via a jumper flowline connector 760. In this embodiment, the in-line tee arrangement 710 is therefore operable to receive fluid from multiple subsea wells (not shown) via jumper flowlines 738 and 739. It will be appreciated that in alternative arrangements, a single bore module of this type can alternatively be used to facilitate connection of the in-line tee to a process apparatus, such as a single bore process apparatus.
Alternatively,
The in-line tee arrangement is integrated into the pipeline 812, and receives flow in the direction of the arrows shown. The pipeline 812 is connected to a production riser, into which flow is routed upon its exit from the in-line tee 814 in the direction shown by arrow B. In the embodiment of
A retrievable gas lift apparatus 860 is connected to a single bore 833 of the module interface. However, it will be appreciated that alternative apparatus may connect to both bores, or multiple bores where provided by the interface. The gas lift apparatus 860 comprises an inlet 861 for one or more gas lift delivery lines 862. An injection check valve 864 and an injection nozzle 866 to control injection of gas from the delivery line(s) 862 and into the main flowline 825 of the in-line tee, where it mixes with production flow from the pipeline 812. The injected gas decreases the density of the production flow exiting the in-line tee, thus aiding and/or increasing recovery up the riser.
The apparatus 860 also comprises a pressure and temperature transducer (PTT) 868 to measure characteristics of the fluid within the apparatus 860. The PTT receives electrical power from a line 872 from an umbilical (not shown). Likewise, a valve 874 which controls the inlet of gas into the system is hydraulically actuated, with hydraulics provided from a line 870 from the umbilical.
With reference now to
In addition, a hydraulic intervention point is provided via a hot stab receptacle 980 in the apparatus 960.
Like the in-line tees described in the foregoing description, the in-line tee 1714 is a stripped back and simplified in-line tee structure, which is devoid of the instrumentation and valving which is typically required for its use with any subsea flow system. The removable module 1728 facilitates connection of the gas lift apparatus 1760 to the tee 1714.
In this embodiment, the removable module 1728 is additionally provided with an interface 1782 to connect with an umbilical termination head (UTH) (not shown) to fluidly connect incoming gas lift and hydraulic control lines to corresponding lines provided within the module 1728. The interface 1782 may also facilitate connection to chemical lines containing methanol, for example. The module 1728 comprises a second outgoing interface 1784 for onward connection to a corresponding interface 1786 on the gas lift apparatus 1760, when installed upon the module 1728. When the second interface 1784 is unconnected, the fluids within the control lines are fully isolated by the removable module.
This arrangement of the removable module 1728 is beneficial because the interface 1782 allows the removable module to be installed upon the tee 1714 and connected to the various hydraulic and gas lift lines in the first instance. Then, when the gas list apparatus 1760 is installed (if and when required in the future), it is simply be connected to the outgoing interface 1784 of the module 1728 using the necessary lines 1787, instead of having to be connected to the UTH.
The gas lift apparatus 1760 is fully retrievable from the removable module 1728, such that the installed in-line tee 1714 is undisturbed during its recovery, replacement or change out (for example, for a variety kind of gas lift apparatus).
Although an orifice is shown as the gas lift nozzle, it will be appreciated that in alternative embodiments a choke valve could be used. In addition, the provision of transducers, other instrumentation and valving within the module can vary without materially effecting the function of the gas lift apparatus and operation.
In operation, the removable module 1728 receives gas from the gas delivery line via the interface 1782 and routes this to the gas lift apparatus 1760 via the interfaces 1784 and 1786. Gas is injected into the production pipeline in the same manner as described with reference to
The in-line tee apparatus 1010 is connected to a process apparatus 1040. In this embodiment of the invention, the process apparatus 1040 is a production choke and metering module. The production choke 1078 is displaced from the Christmas tree and instead provided in the apparatus 1040. Therefore, the in-line tee arrangement 1010 is capable of supporting the production choke 1078 required by the Christmas tree. In addition, the apparatus 1040 contains a pair of chemical injection throttle valves 1079 which control the flow of chemical injection fluid from fluid delivery lines 1080 through the apparatus 1040 and onward to the Christmas tree in the direction of arrow C. The apparatus 1040 also contains a flowmeter 1082 for production fluid. A subsea electronics module 1071 receives electrical power from a line 1072 from an umbilical (not shown) and operates the numerous valves, sensors and meters contained within the apparatus 1040. In operation, fluid which is produced from a subsea well (not shown) is routed into a subsea Christmas tree 1076. Fluid exits the Christmas tree via a jumper flowline 1038. The jumper flowline is connected to the removable module 1028 of the in-line tee arrangement 1010 such that production fluid flows into the removable module 1028 from the jumper flowline 1038. Flow is then routed through the production flow meter and choke apparatus 1040, in which any desired flow monitoring and/or control steps may be performed. Upon exiting the apparatus 1040, flow re-enters the removable module 1028 before being routed through the in-line tee 1014 to commingle with production fluid from one or more wells in the main production pipeline 1012.
In the embodiment shown in
Referring now to
A process apparatus 1340 comprising two hydraulic lines 1369b, 1370b and one electrical line 1372b is shown before and after connection to the removable module 1328. These lines 1369b, 1370b, 1372b are connected to the control interface 1392 of the module 1328 to receive hydraulic and electrical control. The lines 1369b, 1370b, 1372b may be utilised by the process apparatus 1340 itself, and/or may be directed towards a further piece of equipment or subsea infrastructure.
Providing a removable module that is pre-installed with control lines is beneficial as this reduces the need to carry out additional installation steps in the future. For example, the pre-installed control lines mean that a process apparatus which requires such control can simply be connected to the removable module and to the control supply lines in one step. In contrast, where a removable module does not comprise control lines pre-installed, connection of a process apparatus to the removable module and to separate control lines from a control umbilical will require additional installation steps.
The removable module 1428 of
The removable module may be utilised as a spacer module having the purpose of providing a spacer between the tee and another flow component, such as a jumper flowline or process apparatus. This type of module may be required for flowline and/or flow system geometry reasons.
In the configuration of
Sensors, such as temperature and/or pressure sensors or additional instrumentation may also be provided in any of the retrievable modules described in the foregoing description, in communication with the main flow bore or bores therein. It will also be appreciated that any of the in-line tees described within this specification may be provided with an isolation valve operable to close off the branched tie-in flow path or paths.
The invention provides a subsea in-line tee arrangement for a subsea production system comprising a simplified in-line tee and a removable module and methods of installation and use. The arrangement has the capability to provide greater functionality to the in-line tee via retrievable process apparatus, whilst allowing the in-line tee to be reduced in size and weight; factors which simplify the installation of the pipeline into which the in-line tee is integrated and which reduce any damage caused to the pipeline by the in-line tee during installation. As the simplified in-line tee is smaller than typical in-line tees, it will be easier to weld (or otherwise connect) the tee into the pipeline before it is deployed subsea. This will be beneficial to the spatial constraints of pipe-lay vessels. Similarly, the smaller size of the simplified in-line tee will allow it to get through tensioners onboard the pipe-lay vessels without any issues.
The invention provides a subsea in-line tee arrangement for a subsea production system comprising at least one removable module. At least one retrievable process apparatus can be connected to the retrievable module. The at least one retrievable process apparatus is configured to perform a function selected from the group comprising: fluid control, fluid sampling, fluid diversion, fluid recovery, fluid injection, fluid circulation, fluid measurement and/or fluid metering.
Various modifications to the above-described embodiments may be made within the scope of the invention, and the invention extends to combinations of features other than those expressly claimed herein.
| Number | Date | Country | Kind |
|---|---|---|---|
| 1901257 | Jan 2019 | GB | national |
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/GB2020/050222 | 1/30/2020 | WO |
| Publishing Document | Publishing Date | Country | Kind |
|---|---|---|---|
| WO2020/157509 | 8/6/2020 | WO | A |
| Number | Name | Date | Kind |
|---|---|---|---|
| 8550170 | McHugh et al. | Oct 2013 | B2 |
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| Number | Date | Country |
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| Entry |
|---|
| International Searching Authority, Indian Patent Office, International Search Report and Written Opinion for PCT/GB2021/050902, date mailed: Jul. 29, 2021, 10 pages. |
| Number | Date | Country | |
|---|---|---|---|
| 20220090471 A1 | Mar 2022 | US |
