US20180258742A1 - Subsea manifold system - Google Patents
Subsea manifold system Download PDFInfo
- Publication number
- US20180258742A1 US20180258742A1 US15/537,105 US201515537105A US2018258742A1 US 20180258742 A1 US20180258742 A1 US 20180258742A1 US 201515537105 A US201515537105 A US 201515537105A US 2018258742 A1 US2018258742 A1 US 2018258742A1
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- Prior art keywords
- manifold
- hub
- connections
- primary manifold
- extension
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
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- 238000004519 manufacturing process Methods 0.000 claims abstract description 41
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 36
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 36
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 24
- 239000012530 fluid Substances 0.000 claims description 33
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 28
- 238000002347 injection Methods 0.000 claims description 21
- 239000007924 injection Substances 0.000 claims description 21
- 239000012071 phase Substances 0.000 claims description 10
- 238000012545 processing Methods 0.000 claims description 9
- 238000000034 method Methods 0.000 claims description 8
- 239000007791 liquid phase Substances 0.000 claims description 7
- 238000004891 communication Methods 0.000 claims description 6
- 238000000926 separation method Methods 0.000 claims description 3
- 238000005086 pumping Methods 0.000 abstract description 17
- 239000000126 substance Substances 0.000 description 6
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 4
- 230000004888 barrier function Effects 0.000 description 4
- 238000010586 diagram Methods 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 108010053481 Antifreeze Proteins Proteins 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000002528 anti-freeze Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000004020 conductor Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 150000004677 hydrates Chemical class 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/017—Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
- E21B33/0355—Control systems, e.g. hydraulic, pneumatic, electric, acoustic, for submerged well heads
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/013—Connecting a production flow line to an underwater well head
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/017—Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
- E21B43/0175—Hydraulic schemes for production manifolds
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/08—Underwater guide bases, e.g. drilling templates; Levelling thereof
Abstract
Description
- The present invention relates to a subsea hydrocarbon production hub, and to a subsea hydrocarbon production system incorporating such a hub, which are particularly useful when oil or gas is to be produced from a plurality of fields where at least one is a remote “satellite” field.
- It is well-known that when hydrocarbons (oil and/or gas) are to be produced from a sub-sea reservoir, a top-side facility, such as a production platform or vessel is provided on the surface and well-head is provided on the sea bed. The well-head is located at the top of the well, through which oil and/or gas may flow from the underground reservoir. The well-head is equipped to control the well and has valve and arrangements to prevent leakage from the reservoir.
- The well-head is connected to the top-side facility by means of a production and/or injection flow line running along the sea bed, often for tens of kilometers, and a riser extending upwardly to the top-side facility, also referred to as a platform. Through these, the oil/gas flows to the top-side facility. Also, from the top-side facility, risers for gas lift, gas injection or water injection are connected to the well-head, either via subsea manifolds or directly to the dedicated wells.
- In addition, dedicated umbilicals provide power, control and communications, as well as the supply of chemicals, such as hydraulic fluids and MEG (mono ethylene glycol), which is used as anti-freeze to prevent the formation of hydrates.
- There will typically be a number of well-heads grouped comparatively close together. Rather than having separate risers leading to each, a manifold is normally provided on the sea bed. This will have risers connecting it to the top-side facility to provide the previously-mentioned services. In turn, there are separate connections from the manifold to each of a plurality of well-heads. One example of such a manifold system is disclosed in US 2011/0132615.
- Another known situation is for a so-called satellite field to be developed and produced from the same topside facility. When this is to be done, it can either be achieved by a daisy-chained solution via other templates or by connecting each new satellite field directly to the topside facility. The conventional arrangement is to provide a so-called riser base in association with each wellhead and for the riser base to be connected to the topside facility.
-
FIG. 1 illustrates such a conventional arrangement where a topside facility, in this case the platform, is connected to a standard manifold and to a number of satellite fields. - Referring to that figure, the
platform 1 is shown schematically as having two regions, 2 and 3.Region 2 provides for connection tostandard manifold 4 by means of umbilical 5 which includes various conduits. (In the diagram, C indicates conduits for control, power and fluids (hydraulic, chemicals and barrier fluids). WI indicates water or gas injection, and LP/HP indicate low pressure/high-pressure production respectively.) Manifold 4 is in turn connected to a number of wells 6 (shown here as nos. 1, 2 and 3) by means ofconnectors 7. -
Platform 1 also has aregion 3 for connection to satellite fields. These fields will typically have been developed subsequent to the initial fields. The satellite fields are shown adjacent to the other fields in the figure, but in reality they will be dispersed over a large area of the seabed, often tens of kilometers away. Each satellite field has ariser base umbilicals various satellite fields connections - It will be understood from the figure that each satellite field normally requires dedicated riser(s) between the satellite field and the topside facility, which each must include production lines and provide for injection of gas and water. In addition, there must be umbilical(s), providing conduits for control, power, MEG and various fluids. Accordingly, between two and four riser slots are needed at the topside facility for each satellite field.
- Taking these factors together, the result is that for each single new field, very significant new costs are involved. Whilst these costs may be economically justifiable where the satellite fields in question contain significant reserves of producible hydrocarbons, the development of more marginal fields will not be commercially attractive. In addition, there is a physical limit on the number of available riser slots at the top site facility.
- The present invention aims to address this problem in order to enable production from more marginal satellite fields.
- Viewed from a first aspect there is provided a modular, subsea hydrocarbon production hub comprising a primary manifold and one or more co-located extension structure(s), the primary manifold having first connections for connection to at least a riser and an umbilical from a top-side facility, and second connections for connection to at least one extension structure, wherein at least one of the extension structure(s) comprises a secondary manifold having first connections connected to the second connections of the primary manifold, second connections for connection to at least one further extension structure, and third connections for connection to at least one wellhead or template, the secondary manifold providing for a flow of produced hydrocarbon from the at least one wellhead or template to the top-side facility via the primary manifold and the riser, and facilitating electrical and/or hydraulic control from the top-side facility via the primary manifold and the umbilical.
- The use of such a modular hub facilitates communication between a large number of subsea wells and the surface platform via a small number of risers and umbilicals. Furthermore, the modular configuration means that if additional capacity or functionality is required, for example to produce from new satellite wells or to provide additional subsea processing, then this can be provided simply by connecting further extension structures to the hub. For example, extension manifolds or processing equipment may be connected directly to on spare connections on the primary manifold or an extension structure.
- In the present context, the term “co-located” is intended to mean that the modular components of the hub (the primary manifold and the extension structures) are located in a group or cluster proximate one another in the context of an offshore hydrocarbon production facility, e.g. below a platform. Thus, they are proximate at least relative to a satellite well site, which will be remotely located, often tens of kilometers away. In various embodiments, this could for example be understood to include components within the safety zone surrounding the riser (typically a 500 meter radius around the riser base, or primary manifold in this case). More typically the components of the hub will be closer together and the distance between individual components would typically be well under 100 m, and usually under 50 m. In some embodiments, the components may be directly adjacent and/or mechanically inter-connected (in addition to the fluid/control connections), e.g. bolted together or rigidly connected in some other manner.
- In various embodiments, the primary manifold may provide connection to the secondary manifold (or other extension structure) in respect of any or all of the following services, which will typically connect to the riser: hydrocarbon production, water injection, gas injection, gas lift. Additionally (or alternatively) it may provide any or all of the services provided via the umbilical, such as control, power and/or service fluids (hydraulic, chemicals, barrier fluids).
- Typically, the primary manifold will itself be connected to a wellhead and/or template and indeed, either or both manifolds may be connected to a plurality of wellheads and/or templates. Thus, the primary manifold may also have third connections for connection to at least one wellhead or template. In some implementations, the hub may be installed at an initial well site, and then expanded using extension structures to connect subsea to new satellite sites as they are found or become viable.
- The facilitation of control is preferably provided by the provision of conduits and/or conductors within the riser/umbilical/connector that distribute one or more (and preferably all of) the following services: injection gas and water, electrical power, electrical control signals, communication, chemicals and/or hydraulic power. Corresponding conduits and connections may then be provided within the primary manifold to allow distribution of these services to the secondary manifold(s). Most preferably, each of these services is provided to the hub.
- Thus, by means of the invention, satellites can be added to the overall production system without any increase in the number of risers connected to the top-side facility. Alternatively, where a large number of satellite fields are added, the increase in the number of risers/umbilicals is significantly reduced compared to the prior art. This minimises the number of topside modifications and reduces the overall cost of producing from such satellite fields.
- Preferably, the one or more extension structures include a plurality of secondary manifolds. As discussed above, the modular configuration permits simple enlargement of the capacity of the hub to permit new well sites to be connected and produced. The modular hub is not limited to any specific configuration, and in various embodiments at least two of the secondary manifolds may be connected to the primary manifold or to another extension structure in series, i.e. as a daisy chain, or in parallel, e.g. in as spokes. The specific configurations available will of course depend upon the individual design of the components of the hub and how many ports are available for the second connections on each modular component.
- The hub, and particularly the primary manifold of the hub, preferably also provides valving arrangements so that flow of each of the various production lines may be controlled. (Likewise, switching arrangements may be provided for electrical power, communications and control.) This may be necessary, either to open and close connection ports when secondary manifolds are connected/disconnected, or for control purposes during operation. Such valves may be remotely operated from the surface, automatically operated (e.g. safety cut-off systems) or operable by ROV. Preferably each conduit within the hub may be closed by means of a valve and preferably a valve is provided in association with each connection port thereof.
- The invention of course also extends to the hub when installed. Thus, in a second aspect, the present invention also provides a hydrocarbon production system comprising a top-side production platform connected by means of a riser and an umbilical to a hub on the sea floor as described above, the hub being in turn connected subsea to one or more wells, wherein hydrocarbons produced from each of the wells flow to the platform via a secondary manifold of the hub, the primary manifold of the hub, and the riser, and wherein one or more of service fluids, electrical control signals, electrical power and injection fluids are transmitted to each of the wells via first the primary manifold and then a secondary manifold.
- It will therefore be seen that, in a particularly preferred embodiment, there is provided a production platform connected by means of a riser and an umbilical to a primary manifold on the sea floor. The primary manifold is in turn connected to one or a plurality of secondary manifolds that expand the capacity of the hub. The secondary manifolds are themselves connected to wellheads and hydrocarbons produced from those wellheads flows via the secondary manifold, the primary manifold and then, via a riser, to the platform. At the same time, fluid, electrical control signals, electrical power and/or injection fluids are transmitted to the wellhead via first the primary manifold and then via the secondary manifold.
- Optionally, the primary manifold, a secondary manifold or one or more of the other extension structures may provide ancillary services. Such services may include: processing of produced fluids, such as separation of oil from water and/or gas, oil, gas and water treatment; boosting the fluid by means of a pump or compressor; measuring one or more of the different fluid streams.
- For example, an external pumping unit may be provided in an extension structure which may be used to increase the pressure of produced fluids in order to maintain or increase the production from the satellite field. The pumping unit may be connected to second connections of the primary manifold or an extension structure.
- In another example, one of the extension structures may comprise a separator unit. The separator unit may be connected to second connections of the primary manifold or an extension structure. The separator unit may separate water from a hydrocarbon stream before the hydrocarbon stream is passed to the riser. This reduces the quantity of water raised unnecessarily to the surface. The separated water may be discharged to sea or may be re-injected into a well. The separator unit may additionally or alternatively separates a hydrocarbon gas phase from a hydrocarbon liquid phase. The gas phase can be used to provide gas lift. The liquid phase can be used as a driving medium for an ejector. Alternatively, the gas and liquid phases may be separated to facilitate pumping to the surface as separate phases, which may simplify the pumping equipment required.
- Preferably, means is provided for connection of an external pump/pressure module (to boost pressure of production from satellite fields). To achieve this, most preferably, the second connections include ports that are suitable both for connection to secondary manifold and also for connection to such units.
- Although the invention has been described in the context of both a riser and umbilical being provided between the top-side facility and the subsea manifold, other aspects of the invention may involve only a riser or an umbilical, or pluralities of one or the other.
- The invention also extends to a method of hydrocarbon production comprising the use of the system, or hub of any of the above aspects of the invention.
- Viewed from a third aspect, the present invention also provides a method of connecting a subsea wellhead to a top-side production platform via a modular, subsea hydrocarbon production hub connected to the platform via a riser and an umbilical, the method comprising: connecting a secondary manifold to the subsea hub; and connecting the wellhead subsea to the extension manifold of the hub such that hydrocarbons produced from the wellhead flow to the platform via the hub and the riser, and one or more of service fluids, electrical control signals, electrical power and injection fluids are transmitted to the wellhead via the hub and the umbilical.
- In accordance with this method, a new satellite well or template can be added to an existing subsea hydrocarbon production facility by simply installing a modular extension structure to the hub and connecting the new satellite to the extension structure. This avoids the need for new dedicated risers and umbilicals to be connected from the platform to the site, thereby reducing costs and tie-offs required at the platform, and potentially making new sites economically viable.
- The method may further comprise (remotely) controlling a valving arrangement and/or switching equipment within the hub to permit flow of hydrocarbons and/or control to and from the new extension structure.
- The method may further comprise connecting one of more functional units to the hub, for example to enable processing of the hydrocarbons produced by the satellite well. This may be required where the satellite well has a different composition to existing wells and may require different processing to existing wells, e.g. a higher water or acid gas composition or the like.
- Embodiments of the invention will now be described, by way of example only, and with reference to the accompanying drawings:—
-
FIG. 1 is a of view of a conventional system for producing hydrocarbons from main and satellite fields; -
FIG. 2 is schematic view of the first embodiment of the invention showing a primary manifold connected to two secondary manifolds and a pumping unit; -
FIG. 3 is a schematic view of another of embodiment of the invention which differs from that ofFIG. 2 in that a further pumping unit is shown in the position of one of the extension structures; -
FIG. 4 is a schematic view of a still further embodiment in which a separator is provided in connection with the primary manifold; -
FIG. 5 a schematic diagram of a possible application of the invention to a complex oil field situation; -
FIG. 6 is a schematic view of the network and valves in the primary manifold; -
FIG. 7 is a perspective view corresponding toFIG. 6 ; -
FIG. 8 is a perspective view of a hub including the primary manifold and a pumping unit; and -
FIG. 9 is a sectional view of an umbilical for use with the hubs of the various embodiments. - With reference to
FIG. 2 , there is shown a first embodiment of theinvention 20. Ahost platform 21, at the surface, is connected to asubsea hub 36, on the seabed, by means of risers and umbilicals 23. These correspond to the risers/umbilicals 5 inFIG. 1 . Accordingly, they provide for control, power and fluids (hydraulic, chemicals and/or barrier) (C), low pressure production (LP), high pressure production (HP) and injection of water (or gas) injection (WI). Gas lift may also be provided (not shown). Thehub 36 comprises a primary manifold or “mother structure” 22 that receives the risers andumbilicals 23 from the surface. Theprimary manifold 22 is in turn connected to a plurality of wells 24 (nos. 1, 2 and 3) by means ofconnectors 25, again similarly toFIG. 1 . These are shown as providing production (P), water injection (WI) and control (C), though any or all of the above-mentioned services may also be provided. - The
present embodiment 20 differs significantly from the prior art system shown inFIG. 1 in that thehub 36 has a modular configuration and can be extended after installation using extension structure that increase the capacity or capabilities of theprimary manifold 22. - In
FIG. 2 , thehub 36 comprises two secondary orextension manifolds first extension manifold 26 is connected to theprimary manifold 22 by means ofconnections 27. Thefirst extension structure 26 is adjacent to theprimary manifold 22, generally within about 50 meters and in some cases physically adjoining theprimary manifold 22 with preferablyrigid connections 27 Thefirst extension manifold 26 provides connections to wells 29 (nos. 4 and 5) by means ofconnections 28. These correspond toconnections - The
first extension manifold 26 is in turn connected to an adjacentsecond extension manifold 30 by means ofconnections 31, which can be identical toconnections 27. Thesecond extension structure 30 is in turn connected tofurther satellite wells 32 by means ofconnections 33. - Only two extension manifold are shown in
FIG. 2 . However, it will be appreciated that a third extension manifold may be connected to thesecond extension manifold 30. Likewise further such structures may be daisy-chained together, or connected in parallel. - In addition to being connected to the extension manifold,
primary manifold 22 is shown as being connected to apumping unit 34 by means ofconduits 35. Thepumping unit 24 is an extension structure that serves to pressurise the produced fluids to enable them to be transported to theplatform 21 in cases where one more of the produced wells is at insufficiently high pressure. - As will be discussed further below, the
primary manifold 22 andextension structures subsea hub 36 as desired. - The
hub 36 thus provides for communication between a large number ofsubsea wells surface platform 21 via a small number of risers and umbilicals 23. If additional capacity or functionality is required, for example to produce from new satellite wells, then this can be provided by simply connecting further extension manifolds or other functional units to thehub 36. - The provision of additional subsea functionality is illustrated in
FIG. 3 where asecond embodiment 40 is shown. This corresponds to the first embodiment except that in place ofsecond extension manifold 30, thehub 36 is provided with afurther pumping unit 41. Thus, theprimary manifold 22 is connected both to the second pumping unit 41 (indirectly via the first extension manifold 26) and to thefirst pumping unit 42. - Another example of the provision of additional subsea functionality is illustrated in
FIG. 4 , where the third embodiment 50 is shown. This differs from thesecond embodiment 40 in that, in place offirst pumping unit 42, thehub 36 is provided with aseparator unit 51. The use of asubsea separator unit 51 permits improved efficiency of the hub in this embodiment 50. - Produced hydrocarbons often contain substantial amounts of water. This may include formation water that was trapped in the reservoir, or water injected during production. The
separator unit 51 separates water from produced fluids so that water is not wastefully transported to theplatform 52. This both relieves the riser, as a smaller quantity of fluid must be transported to the surface, as well as reducing the amount of topside water processing required at the processing platform, where space is often limited. The water can be either discharged into the sea (subject to appropriate processing, for example using a further extension structure), or re-injected into an injection well. - As pure phases of liquid and/or gas are more controllable with respect to throttling, boosting and transporting than a two- or three phase mixture, the
separator unit 51 can also separate liquid phase and gas phase hydrocarbons from one another. The gas phase may be pressurized as used as lift gas to increase production from a well. Alternatively or in addition, the preferably gas-free liquid phase may be used as a driving medium for an ejector. Ejectors can be used to boost production of an existing well or to restart a “dead” well. - Note that in any of
FIGS. 2 to 4 , the ancillary unit(s) may be provided in addition to the plural extension structures shown inFIG. 2 ; for clarity only a limited number of components are illustrated. -
FIG. 5 shows a possible application of the invention to areas having a number of hydrocarbon producing fields connected to the platform. - Here,
production platform 61 is above the original well site and is connected directly to the initialsubsea template 62 in a conventional manner. Previously, theplatform 61 would have been connected directly to thesatellite subsea templates 63 and 64 (for example, with reference toFIG. 1 ,manifold 4 might have been at the initial site andriser bases subsea hub 65 is instead provided in direct connection with theplatform 61. Thesatellite templates hub 65, instead of being connected directly to the platform. - This facilitates a reduction in the number of risers and umbilicals required to connect these
templates platform 61. Additionally, the invention enables satellite fields C, D, E, which would previously have been economically unviable, to be produced. Using the present invention, an extension manifold and any other required extension structures can be added to thehub 65, andproduction templates hub 65. Field C is to be produced initially, with fields D and E being added later (hence they are shown in phantom). - The application of the invention to this oil field provides a number of the advantages described previously. In particular, there is a reduced need for riser hang-offs at the
production platform 61. It also makes it easier to provide subsea water separation and pressure boosting, again as previously described. Furthermore, the use of a modular construction permits the capacity of thehub 65 to be increased to allow further satellite wells to be produced, without the need for new risers or umbilicals to directly connect the satellite well to theplatform 61. - Details of the primary manifold and extension structures are described now with reference to
FIGS. 6 to 8 . - Schematic pipework diagram 6 shows a
hub 70 having aprimary manifold 71, anextension manifold 72 and apumping unit 73. The physical arrangement of the pipework and valves, etc. may be seen fromFIGS. 7 and 8 . - The arrows at the upper part of
FIG. 6 represent connections to the umbilical and riser which lead to the production platform. Produced oil is shown at 81 and 86, electrical control inputs at 82 and 83, water input at 84, and hydraulic control input at 85. - The connections to the various external units are shown at the lower part of the figure. Production input is at 87, 89 and 93, hydraulic fluid at 88 and 92, with water outlets at 90 and 91. It will also be seen that there are provided flow paths between each of the respective inputs and outputs and that control valves are provided in each line.
-
Connections external pump 73, withconnections - Pumping
unit 73 comprises an input and output conduit for connection to theprimary manifold 71, plus an internal pump and a control valve. -
FIG. 8 shows the pipework ofFIG. 7 mounted to a support cradle and connected to theexternal pumping unit 73, thus corresponding toFIGS. 6 and 7 . -
FIG. 9 illustrates a cross-section through an umbilical used to connect the hub to the platform. It provides the following services:— -
- 36× MEG tubes
- 6× low pressure hydraulic fluid tubes
- 6× high pressure hydraulic fluid tubes
- 6× chemicals tubes
- 2× barrier fluid tubes
- 4× spares hydraulic fluid tubes
- 33× FO cables
- 10× electrical quads (3-phase and earth)
- 4× spares electrical quads
- 2×
HV triads 12 kV, 120 mm2
- In use, the various control valves provided at the hub and elsewhere will normally be operated by remotely operated vehicles. However, certain safety critical valves may be controlled remotely and all by means of automatic operation based at the hub.
Claims (15)
Applications Claiming Priority (3)
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GB1422798.7 | 2014-12-19 | ||
GB201422798 | 2014-12-19 | ||
PCT/NO2015/050254 WO2016099291A1 (en) | 2014-12-19 | 2015-12-18 | Subsea manifold system |
Publications (1)
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US20180258742A1 true US20180258742A1 (en) | 2018-09-13 |
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ID=55311256
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US15/537,105 Abandoned US20180258742A1 (en) | 2014-12-19 | 2015-12-18 | Subsea manifold system |
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US (1) | US20180258742A1 (en) |
AU (1) | AU2015363810B2 (en) |
BR (1) | BR112017012754A2 (en) |
CA (1) | CA2970442A1 (en) |
GB (1) | GB2536763B (en) |
MX (1) | MX2017007818A (en) |
NO (1) | NO20171165A1 (en) |
RU (1) | RU2721204C2 (en) |
WO (1) | WO2016099291A1 (en) |
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US20170146189A1 (en) * | 2014-05-30 | 2017-05-25 | Ge Oil & Gas Pressure Control Lp | Remote well servicing systems and methods |
US20190120020A1 (en) * | 2016-04-04 | 2019-04-25 | Forsys Subsea Limited | Pipeline integrated manifold |
US10400528B2 (en) * | 2016-08-01 | 2019-09-03 | Onesubsea Ip Uk Limited | Modular manifold |
US10619471B2 (en) | 2014-05-30 | 2020-04-14 | Ge Oil & Gas Pressure Control Lp | Remote mobile operation and diagnostic center for frac services |
CN111236893A (en) * | 2020-01-02 | 2020-06-05 | 海洋石油工程股份有限公司 | Underwater production system expansion tie-back facility |
US10982808B2 (en) * | 2019-05-08 | 2021-04-20 | Fmg Technologies, Inc. | Valve control and/or lubrication system |
US20210372272A1 (en) * | 2018-11-13 | 2021-12-02 | Vault Pressure Control Llc | Surface completion system for operations and monitoring |
WO2022128157A1 (en) * | 2020-12-15 | 2022-06-23 | Vetco Gray Scandinavia As | Compact dual header manifold layout |
US11466536B2 (en) | 2019-10-04 | 2022-10-11 | Vault Pressure Control, Llc | Hydraulic override for confined space |
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GB2564138B (en) | 2017-07-04 | 2020-03-11 | Acergy France SAS | Subsea manifolds |
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RU2330154C1 (en) * | 2004-05-03 | 2008-07-27 | Эксонмобил Апстрим Рисерч Компани , | System and vessel for technical servicing of offshore deposits |
AU2007299803B2 (en) * | 2006-09-21 | 2010-09-16 | Shell Internationale Research Maatschappij B.V. | Systems and methods for drilling and producing subsea fields |
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WO2009148943A1 (en) * | 2008-06-03 | 2009-12-10 | Shell Oil Company | Offshore drilling and production systems and methods |
US8950497B2 (en) * | 2012-04-23 | 2015-02-10 | Chevron U.S.A. Inc. | Assemblies, systems and methods for installing multiple subsea functional lines |
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2015
- 2015-12-18 WO PCT/NO2015/050254 patent/WO2016099291A1/en active Application Filing
- 2015-12-18 US US15/537,105 patent/US20180258742A1/en not_active Abandoned
- 2015-12-18 BR BR112017012754A patent/BR112017012754A2/en not_active Application Discontinuation
- 2015-12-18 RU RU2017125498A patent/RU2721204C2/en active
- 2015-12-18 AU AU2015363810A patent/AU2015363810B2/en not_active Ceased
- 2015-12-18 MX MX2017007818A patent/MX2017007818A/en unknown
- 2015-12-18 GB GB1522425.6A patent/GB2536763B/en not_active Expired - Fee Related
- 2015-12-18 CA CA2970442A patent/CA2970442A1/en active Pending
-
2017
- 2017-07-13 NO NO20171165A patent/NO20171165A1/en not_active Application Discontinuation
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US11053746B2 (en) * | 2016-04-04 | 2021-07-06 | Technip Uk Ltd | Pipeline integrated manifold |
US20190120020A1 (en) * | 2016-04-04 | 2019-04-25 | Forsys Subsea Limited | Pipeline integrated manifold |
US10400528B2 (en) * | 2016-08-01 | 2019-09-03 | Onesubsea Ip Uk Limited | Modular manifold |
US11230917B2 (en) | 2018-11-13 | 2022-01-25 | Vault Pressure Control Llc | Surface completion system for operations and monitoring |
US20210372272A1 (en) * | 2018-11-13 | 2021-12-02 | Vault Pressure Control Llc | Surface completion system for operations and monitoring |
US11708756B2 (en) * | 2018-11-13 | 2023-07-25 | Vault Pressure Control Llc | Surface completion system for operations and monitoring |
US10982808B2 (en) * | 2019-05-08 | 2021-04-20 | Fmg Technologies, Inc. | Valve control and/or lubrication system |
US11402064B2 (en) | 2019-05-08 | 2022-08-02 | Fmc Technologies, Inc. | Valve control and/or lubrication system |
US11466536B2 (en) | 2019-10-04 | 2022-10-11 | Vault Pressure Control, Llc | Hydraulic override for confined space |
CN111236893A (en) * | 2020-01-02 | 2020-06-05 | 海洋石油工程股份有限公司 | Underwater production system expansion tie-back facility |
WO2022128157A1 (en) * | 2020-12-15 | 2022-06-23 | Vetco Gray Scandinavia As | Compact dual header manifold layout |
Also Published As
Publication number | Publication date |
---|---|
WO2016099291A1 (en) | 2016-06-23 |
MX2017007818A (en) | 2018-01-11 |
GB201522425D0 (en) | 2016-02-03 |
RU2721204C2 (en) | 2020-05-18 |
RU2017125498A (en) | 2019-01-21 |
AU2015363810B2 (en) | 2020-04-30 |
RU2017125498A3 (en) | 2019-06-04 |
NO20171165A1 (en) | 2017-07-13 |
CA2970442A1 (en) | 2016-06-23 |
GB2536763B (en) | 2017-05-17 |
BR112017012754A2 (en) | 2017-12-26 |
GB2536763A (en) | 2016-09-28 |
AU2015363810A1 (en) | 2017-06-29 |
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