UNITS TO CONNECT SUBMARINE RISER TO ANCHORAGE IN THE SEA BED AND THE SOURCE OF FLUID CARBONES AND TH

专利摘要:
unit for connecting subsea riser to seabed anchorage and the source of fluid carbides and subsea flotation device and surface structure the present invention relates to a lower riser unit that connects to an anchorage on the seabed and a source of fluid carbides. the unit includes a sufficient number of intake ports to accommodate the flow of hydrocarbons from the source of fluid hydrocarbons, as well as the inflow of an optional flow guarantee flow. the upper end of the limb has a suitable profile to connect fluidly to the riser. the lower end of the limb includes a connector suitable for connecting to the anchorage on the seabed. moreover, the present invention also relates to an upper riser unit that connects the riser to an underwater flotation device close to the surface and to a structure on the surface. the unit includes a sufficient number of outlet ports to accommodate the flow of hydrocarbons from the riser through a flexible subsea conduit until it reaches the surface structure. the upper end of the limb includes a connector for connecting to an underwater flotation device. the lower end of the limb has a suitable profile to fluently connect to the riser.
公开号:BR112013006446B1
申请号:R112013006446-3
申请日:2011-10-11
公开日:2020-08-11
发明作者:Steve Hatton；Roy Shilling；Dr. Kevin Kennelley；Robertt W. Franklin；Chau Nguyen；Vicki Corso；Adam L. Ballard；Ricky Thethi
申请人:Bp Corporation Norh America Inc；
IPC主号:

专利说明:

Technical Field
[0001] In general terms, the present invention relates to units useful in marine hydrocarbon exploration, hydrocarbon production, well drilling, well completion, well intervention, and hydrocarbon storage and disposal. More specifically, the present invention relates to upper and lower riser units used with risers for the purposes listed above. State of the art
[0002] Self-sufficient riser systems (FSR) have been used in production and completion operations. For an analysis, see Hatton et al., “Recent Developments in Free Standing Riser Technology”, 3rd Workshop on Subsea Pipelines, December 3 and 4, 2002, Rio de Janeiro, Brazil. For other examples of FSR systems, see United States Patent Applications published 2007/0044972 and 2008/0223583, as well as United States Patents 4,234,047, 4,646,840, 4,762,180, 6,082,391, 6,321,844 and 7,434,624.
[0003] The recommended practice of the American Petroleum Institute (API) 2RD, “Design of Risers for Floating Production Systems (FPSs) and Tension-Leg Platforms (TLPsf, (API-RP-2RD, first edition, June 1998), is a pattern known to those working in the oil and gas production sector.
[0004] Szucs et al .., “Heavy Oil Gas Lift Using the COR, SPE 97749 (2005), reveal a lower riser unit (LRA) in an FSR.
[0005] Tieback connectors are characterized as "internal" and "external" tieback connectors, both patented. Patents on internal tieback connectors include United States Patents 6,260,624, 5,299,642, 5,222,560, 5,259,459, 4,893,842, 4,976,458, 7,735,562, 5,279,369 and 5,775,427 and the Order of United States patent published 2009/0277645. Patents on external tieback connectors include United States Patents 4,606,557, 6,234,252, 6,540,024, 6,070,669, 6,293,343, 7,503,391, 7,337,848, 5,330,201, 5,255,743 and 7,240,735 . Drill adapters and their connection to wellheads (casing heads or tubing heads) are described in United States Patent Application published no. 2009/0032265. Adjustable hangers are described in United States Patents 6,065,542, 6,557,644 and 7,219,738.
[0006] Due to the complexities of any given reservoir, well design and riser system, although certain minimum standards presented in the standard for API risers mentioned above are known to those skilled in the art, each specific oil and gas well may include a environment exclusive to you (see, for example, United States Patent No. 6,747,569). Riser systems that work for a reservoir / well / environment may not be suitable for use in other wells, even if they are close to those.
[0007] There is no knowledge of submarine risers (self-sufficient or not) for use in the context of containment and disposal. More specifically, until recently, the sector has not had to intervene in submarine leaks at significant depths, such as 5,000 feet / 1,500 meters or more. More specifically, previous containment attempts did not take into account the fluid properties generated by the combination of hydrocarbons with seawater at pressures in deep waters and at temperatures that contribute to the formation of gas hydrates.
[0008] Therefore, the unmet need to design stronger and lower riser units persists, especially when flow assurance is a concern, both during normal production operations and during containment and disposal periods. summary
[0009] According to the present invention, subsea units and methods for producing, installing and using them are described, which reduce or overcome many of the defects of previously known subsea units.
[0010] A first aspect of the invention relates to a unit for connecting an underwater riser to a seabed anchorage and to an underwater source of fluid hydrocarbons, the unit comprising: a broadly cylindrical member with a longitudinal hole, one end bottom, an upper end and a largely cylindrical outer surface, the member comprising a number of intake ports extending from the outer surface to the orifice sufficient to accommodate the flow of hydrocarbons from the fluid hydrocarbon source, as well as the inflow of a fluid functional (flow guarantee fluid or other fluid, for example, a corrosion or scale inhibitor, a stopping fluid and the like), at least one of the intake ports fluidly connected to a production side valve unit, the end upper limb having a profile suitable for fluidly connecting to an underwater riser and the lower extremity of the limb having a suitable connector to connect to an anchorage on the seabed.
[0011] In certain embodiments, the broadly cylindrical member comprises an underwater wellhead housing that is modified by connecting a transition joint to it, the upper end of the underwater wellhead housing connecting fluidly to a tieback connector that connects it fluidly to a riser voltage joint.
[0012] In certain embodiments, the subsea wellhead housing has an internal sealing profile adapted to seal an internal tieback connector, which fluidly connects an internal subsea riser to the subsea wellhead internal sealing profile. In certain embodiments, the internal tieback connector comprises a nasal seal that seals to the underwater wellhead profile, the nasal seal providing pressure integrity between an internal flow path of the internal riser and an annular space between the internal riser and a riser substantially concentric external In certain embodiments, the internal tieback connector engages the subsea wellhead housing and a riser tension joint, thus forming a preloaded structural connection between the subsea wellhead housing and the internal and external tieback connectors . In certain embodiments, the engagement mechanisms comprise toothed locks.
[0013] Certain embodiments comprise an external connector that engages the tieback connector internal to the subsea wellhead housing.
[0014] In still other units, the production side valve unit connects fluidly to an underwater source via one or more flexible underwater conduits.
[0015] In still other units, the riser voltage joint, in turn, connects fluidly to an external riser.
[0016] In still other units, the transition joint is covered by a first forged end piece with eyebolt that acts as an anchor point for a self-contained riser.
[0017] Still other units comprise valves operated by ROV to control the flow through an internal flow path of the internal riser and through an annular space between the internal riser and a substantially concentric external riser.
[0018] Still other units comprise one or more pressure and / or temperature monitors.
[0019] Still other units comprise one or more hot stab doors for ROV intervention and / or maintenance.
[0020] In some other embodiments, the broadly cylindrical member comprises a forged piece of high-strength metal. These embodiments may comprise two intake ports connected to respective side valve units and a third port with a subunit suitable for connecting to a source of functional fluid, for example, a flow guarantee fluid or other fluid. The subunit can include one or more valves operable by ROV.
[0021] Certain embodiments comprise two or more intake ports connected to the respective side valve units and also comprise two clamp supports to support two respective subsea connectors, each of which is connected fluidly to the forged member in high strength steel by means of respective block elbows, where each production side valve unit includes at least one ROV-operable valve.
[0022] In certain embodiments, the broadly cylindrical member comprises a third door suitable for connection with a subunit of access to the annular space, which connects to the third door of the forged member in high strength steel by means of a third block elbow and which establishes a fluid connection with a source of functional fluid, such as a flow guarantee fluid or other fluid. In some embodiments, the annular space access subunit comprises one or more valves operable by ROV.
[0023] In certain embodiments, each side valve unit comprises a block elbow that connects it to the metal forged part, at least one ROV-operable valve connected to the block elbow and a subsea connector to connect to a flexible subsea conduit , the block elbow, the ROV-operable valve and the underwater connector, all connected fluidly by central holes that allow fluid communication of the flexible underwater conduit with the longitudinal hole of the metal forged part.
[0024] Certain embodiments comprise a tieback ring with a threaded outer part, which matches threads on the inner surface of the metal forged part, and a threaded inner part, which matches threads on an inner lining column.
[0025] In other embodiments, the forged member of high-strength steel also comprises an internal surface, at least part of which is threaded to screw on matching threads in a tieback ring, which includes at least one set of internal threads that it matches a set of threads on the internal riser and which also includes a sealing element made of Inconel or another corrosion resistant metal.
[0026] Certain embodiments comprise a hot stab unit for injecting a functional fluid, which enables a flow rate of the functional fluid to be lower than would be possible through the subunit of access to the annular space.
[0027] In other embodiments, the broadly cylindrical member comprises an intake cylinder forged from high-strength steel fluidly connected to a curved unit, which fluidly connects to the lower flexible conduit, the intake cylinder further comprising a connector that allows the connection to a source of functional fluid. In some embodiments, the curved unit comprises a submarine API flange connected in series to a pipe cylinder, a high pressure submarine connector, another submarine API flange and a curvature restrictor.
[0028] In other embodiments, the intake cylinder comprises an internal surface adapted to accept and fluidly connect to an internal tieback connector that rests on the internal surface of the intake cylinder, which further comprises a latching mechanism that allows the internal tieback connector connects remotely to it, while an O-ring establishes a fluid tight seal between the outer surface of the inner tieback connector and the inner surface of the intake cylinder.
[0029] Another aspect of the present invention relates to a unit suitable for use as an underwater undersea riser unit, which comprises: an underwater wellhead housing with a lower end and an upper end, the lower end being modified by connecting a transition joint is fluidly and mechanically connected to it, which in turn fluidly and mechanically connects to a base forgery, which comprises a sufficient number of intake ports to accommodate the flow of production fluids or containment and a flow guarantee fluid, at least one of the ports connected to a flow guarantee fluid source, at least one other intake port fluidly connected to a production side valve unit, the upper end of the head housing subsea well fluidly connected to an external tieback connector, which fluidly connects the subsea wellhead housing to a riser tension joint, the subsea wellhead having an internal sealing profile adapted to seal an internal tieback connector, which fluidly connects an internal subsea riser to the internal sealing profile of the subsea wellhead, where the internal tieback connector comprises a nasal seal sealing to the underwater wellhead profile, the nasal seal providing pressure integrity between an internal flow path of the internal riser and an annular space between the internal riser and a substantially concentric external riser, and in which the internal tieback connector engages to the subsea wellhead housing and a riser tension joint, thus forming a preloaded structural connection between the subsea wellhead housing and the internal and external tieback connectors.
[0030] Another aspect of the present invention relates to a unit suitable for use as a submarine lower riser unit, which comprises: a highly cylindrical high strength metal forged piece comprising a longitudinal hole, a lower end, an end upper, broadly cylindrical outer surface and a sufficient number of intake ports to accommodate the flow of production or containment fluids, at least one of the ports connected to a flow guarantee fluid source, at least one other fluidly connected intake port to a production side valve unit, the upper end of the metal forged part having a profile suitable for fluidly connecting to an external undersea riser, the lower end of the metal forged part comprising a connector suitable for connecting to an undersea anchorage , a third port suitable for connection with a subunit of access to the annular space, which comprises one or more valves operable by underwater remote control vehicle (ROV), and a tieback ring with a threaded outer part, which matches threads on the inner surface of the metal forged part, and a threaded inner part, which matches threads in an internal lining column.
[0031] Another aspect of the present invention relates to a unit suitable for use as an underwater subsea riser unit, which comprises: an intake cylinder forged from high strength steel and largely cylindrical connected fluidly to a curved unit, which connects fluidly to the lower flexible conduit, the intake cylinder also comprising a connector that allows connection to a source of functional fluid; the curved unit comprising a submarine API flange connected in series to a pipe cylinder, a high pressure submarine connector, another submarine API flange and a curvature restrictor; and wherein the intake cylinder comprises an inner surface adapted to accept and fluidly connect to an internal tieback connector that rests on the internal surface of the intake cylinder, which further comprises a latching mechanism that allows the internal tieback connector to connect it is removable to it, while an O-ring establishes a fluid-tight seal between the outer surface of the inner tieback connector and the inner surface of the intake cylinder.
[0032] Another aspect of the present invention relates to a unit for connecting an underwater riser to a subsea flotation device and to a structure on the surface, the unit comprising: a broadly cylindrical member with a longitudinal hole, a lower end, a upper end and a broadly cylindrical outer surface, the member comprising a number of outlet ports extending from the orifice to the broadly cylindrical outer surface sufficient to accommodate the flow of hydrocarbons from the riser and at least one port to allow fluid flow functional to the longitudinal orifice, at least one of the outlet ports fluidly connected to a production side valve unit to fluidly connect the member to the structure on the surface by means of a flexible subsea conduit, the upper end of the member having a connector suitable for connect to an underwater flotation device, and the lower end of the t member providing a suitable profile to seamlessly connect to the riser.
[0033] In certain embodiments, the broadly cylindrical member comprises a drill adapter cylinder with a first end fluidly connected to a pipe head, which comprises one or more outlet ports and connects to a casing head with a gasket on a rod connected (e.g., welded) to it, the casing head further comprising one or more ports for admitting a functional fluid and one or more side production valve units fluidly connected to the respective outlet ports.
[0034] In certain embodiments of this aspect, rod joint connects fluidly to a concentric external riser.
[0035] In certain embodiments, at least one of the production side valve units fluidly connects an outlet port to a collection vessel via a flexible conduit.
[0036] In certain embodiments, the unit comprises an adjustable pipe hanger that fluidly connects an internal riser to the pipe head.
[0037] In yet other embodiments of this aspect, the production side valve unit comprises first and second flow control valves to control the flow in the orifice of the internal riser and in an annular space between the internal and external risers.
[0038] In still other embodiments, the production side valve unit comprises at least one emergency shutdown valve (ESD) selected from the group consisting of an ESD valve operated hydraulically, electronically or both.
[0039] In yet other embodiments, the production side valve unit comprises one or more hot stab ROV ports that allow a functional fluid to penetrate the internal riser and an annular space between the internal riser and an external riser. In certain embodiments, the functional fluid is a flow guarantee fluid selected from the group consisting of nitrogen or other gaseous phase, sea water or other heated water and organic chemicals. In certain embodiments, the flow guarantee fluid is essentially composed of nitrogen.
[0040] In certain embodiments, the drill adapter cylinder connects to a shackle adapter flange placed on it with a terminal forged piece with eyelet, which acts as the unit's connection point with an underwater flotation unit close to the surface .
[0041] In other embodiments of this aspect of the present invention, the broadly cylindrical member comprises an outlet cylinder with an upper end, a lower end, an eyelet flange connected to the upper end of the outlet cylinder and a suspension cylinder connected to the end bottom of the outlet cylinder, where the outlet cylinder and the suspension cylinder define the longitudinal hole.
[0042] In some of these embodiments, the outlet cylinder comprises a second orifice substantially perpendicular to the longitudinal orifice and which fluidly connects the longitudinal orifice to one of the production side valve units via one of the outlet ports.
[0043] In some other embodiments, the production side valve unit comprises a curved conduit and two emergency shut-off valves (ESD) connected fluidly in line to the curved conduit, one of the ESD valves being actuated hydraulically and the other electronically.
[0044] In some other embodiments, the suspension cylinder comprises a third orifice substantially perpendicular to the longitudinal orifice and which fluidly connects to an annular space defined by the suspension cylinder and an internal riser gasket to a space access valve unit. ring. The annular space access valve unit may comprise one or more ROV-operable valves. The annular space access valve unit can fluidly connect to a functional fluid source.
[0045] Certain embodiments comprise a riser locking unit to interface with the internal riser gasket and keep it inside the outlet cylinder. The riser locking unit may comprise a containment ring and a wedge with T-seals.
[0046] In certain embodiments, two sealing ring and wire retainer structures are arranged on the inner surface of the outlet cylinder to establish a double fluid tight seal between the annular space and the longitudinal orifice.
[0047] In certain embodiments, the IVR comprises an outlet cylinder with a production orifice connected mechanically and fluidly to a substantially vertical duct and to a production pipeline, which, in turn, connects fluidly to a curvature restrictor by via a submarine API flange, a high pressure submarine connector, another submarine API flange connection and, optionally, a QDC submarine connector. The curvature restrictor mechanically connects to the upper submarine flexible conduit, which extends in a catenary to the collection vessel on the surface, and the substantially vertical conduit connects fluently in series to an adapter, which, in turn, connects connects fluidly to an API cylinder and suspension cylinder, to a casing head via another API flange, to a rod joint welded to the casing head and to the external riser via a threaded connection with a rod joint, the outlet cylinder including a shackle flange that allows connection to the undersea flotation device.
[0048] In certain embodiments, the IVR further comprises an ESD valve operable by ROV fluidly connected to a section of the duct.
[0049] In certain embodiments, the IVR also comprises an angular support that supports the production pipeline at an angle that of the duct and that also supports a bending bulkhead that provides a mechanical barrier between the production pipeline and the duct, where the angle o ranges from 0 to about 180 °.
[0050] In certain embodiments, the IVR also comprises a connector on the suspension cylinder to connect to a curved pipe for feeding heated water to the suspension cylinder from a vessel on the surface.
[0051] In certain embodiments, the curved tubing comprises, in the order beginning with the suspension cylinder, an API flange, a tubing section, a high pressure submarine connector, an underwater API connector and API flange and a curvature restrictor.
[0052] In certain embodiments, the internal riser is arranged inside the adapter, the suspension cylinder and the coating head, thus forming an annular space between the internal surface of the suspension cylinder and the internal riser.
[0053] In certain embodiments, the IVR comprises a pair of O-ring seals, which seal the internal riser to the adapter, and one or more shims, which are arranged between an internal inclined surface of the suspension cylinder and the riser thus securing the internal riser firmly to the suspension cylinder.
[0054] In some embodiments, the IVR also comprises components that allow the circulation of a functional fluid, such as heated water, through the annular space.
[0055] In other embodiments, the IVR also comprises an outlet cylinder fluidly connected to a suspension cylinder, which, in turn, fluidly connects to a riser-tensioned gasket.
[0056] In still other embodiments, the IVR also comprises a shackle and a chain that allow it to mechanically connect to a flotation device close to the surface.
[0057] Some other embodiments comprise a first block elbow with an internal hole that intersects with a hole in the outlet cylinder and is substantially perpendicular to it, a second block elbow with an internal hole substantially perpendicular to the hole in the outlet cylinder , but which does not intersect it, and a curved duct fluidly connected to the first block elbow, thus establishing a flow path for hydrocarbons together with the orifice in the first block elbow. In some cases, the IVR comprises first and second emergency shutoff valves in the curved conduit, which connects fluidly to a subsea connector which, in turn, connects to the flexible subsea conduit.
[0058] In other embodiments, the unit also comprises a bleed valve in the curved conduit that allows the IVR to be paralyzed, bleed contents from the curved conduit and recover the submarine flexible conduit.
[0059] In some embodiments, the components that allow the circulation of a functional fluid through the annular space comprise an underwater connector, a conduit and one or more valves in the conduit, which connects fluidly to the suspension cylinder.
[0060] Yet another aspect of the present invention relates to a unit suitable for use as an underwater subsea riser unit, which comprises: a drill adapter cylinder with a first end fluidly connected to a pipe head, which comprises a or more outlet ports and connects to a casing head with a stem gasket attached to it, the casing head further comprising one or more ports for admitting flow guarantee fluid, the stem gasket fluidly connected to a concentric external riser, an adjustable pipe hanger to fluidly connect an internal riser to the pipe head, thus forming an annular space between the internal riser and the concentric external riser, a production side valve unit fluidly connected to one of the respective output, the production side valve unit comprising first and second flow control valves to control the flow in the internal riser inside and in the annular space, and a hydraulically operated emergency shutoff valve and an electrically operated emergency shutoff valve and the production side valve unit comprising one or more hot stab ROV ports that allow a flow guarantee fluid flow into the internal riser and / or the annular space.
[0061] Yet another aspect of the present invention relates to a unit suitable for use as an underwater top riser unit, which comprises: an outlet cylinder with an upper end and a lower end, an eyebolt flange connected to the upper end and a suspension cylinder connected to the lower end, wherein the outlet cylinder and the suspension cylinder define a longitudinal orifice, the outlet cylinder comprising a second orifice substantially perpendicular to the longitudinal orifice and which fluidly connects the longitudinal orifice to a unit production side valve through an outlet port on the output cylinder, the production side valve unit comprising a curved duct and two emergency shut-off valves (ESD) connected fluidly in line to the curved duct, one of the ESD valves being driven hydraulic and the other electronically, the suspension cylinder comprising a third subs orifice substantially perpendicular to the longitudinal orifice to fluidly connect an annular space defined by the suspension cylinder and an internal riser gasket to an annular space access valve unit, which comprises one or more valves operable by ROV, a locking unit of the riser to interface with the internal riser gasket and keep it inside the outlet cylinder, the riser locking unit comprising a containment ring and a shim with T-seals and two sealing ring structures and wire retainer on the internal surface of the outlet cylinder to establish a double fluid tight seal between the annular space and the longitudinal orifice.
[0062] Another aspect of the present invention relates to a unit suitable for use as an underwater subsea riser unit, which comprises: an outlet cylinder with a production orifice connected mechanically and fluidly to a substantially vertical duct and to a production, which, in turn, connects fluidly to a curvature restrictor by means of an undersea API flange, a high-pressure subsea connector, another subsea API flange connection and, as an option, a QDC subsea connector, the restrictor of curvature connected to the upper flexible submarine conduit, which extends in catenary to a structure on the surface, in which the substantially vertical conduit fluidly connects in series to an adapter, which, in turn, connects to a cylinder of suspension by means of an API flange, to a cladding head by means of another API flange, to a rod joint welded to the cladding head and to an external riser by means of a threaded connection with a rod joint, the output cylinder including a flange with shackle that allows connection with an underwater flotation device; an ROV-operable ESD valve fluidly connected to a section of the duct; an angular support that supports the production pipeline at an angle o of the conduit and that also supports a bulkhead against bending that provides a mechanical barrier between the production pipeline and the conduit, where the angle varies from 0 to about 180 °. a connector on the suspension cylinder to connect to a curved pipe to feed heated water to the suspension cylinder from a vessel on the surface, where the curved pipe comprises, in the order starting with the suspension cylinder, an API flange, a section pipe, a high-pressure subsea connector, an API connector and subsea API flange and a curvature restrictor; wherein the internal riser is disposed within the adapter, the suspension cylinder and the coating head, thus forming an annular space between the internal surface of the suspension cylinder and the internal riser; and a pair of O-ring seals, which seal the internal riser to the adapter, and one or more shims, which are arranged between an internal inclined surface of the suspension cylinder and the internal riser, thus securely securing the internal riser in the suspension cylinder.
[0063] In certain embodiments, each of the subsea flexible conduits comprises a flexible cable for calm waves with distributed floating modules connected to the subsea flexible conduit at random or not from a connection point in the subsea flexible conduit based on the self-sufficient riser a a manifold on the seabed, the manifold fluidly connected to one or more underwater sources.
[0064] Certain embodiments include an internal tieback connector that fluidly connects the internal riser to the LRA, the internal tieback connector comprising a nasal seal, which, in some embodiments, is an Inconel nasal seal that seals to a head profile. subsea well, the connector also engages with toothed locks on both the subsea wellhead and the tension joint in order to form a preloaded structural connection between the subsea wellhead and the internal and external tieback connectors. Certain embodiments further comprise an additional external engagement mechanism that engages the internal tieback connector to the subsea wellhead. The nasal seal provides pressure integrity between the internal flow path in the internal riser and the annular space between the internal and external risers.
[0065] Certain embodiments include embodiments in which a production side valve unit in the IVR comprises emergency shut-off valves operated both hydraulically and manually.
[0066] Certain embodiments include embodiments in which the production side valve unit in the IVR comprises one or more underwater hot stab ports to the vessel that allow injecting a functional fluid into one or both of the internal riser and the annular space. Examples of suitable functional fluids include flow guarantee fluids such as a gaseous atmosphere, sea water or other heated water or organic chemicals such as methanol and the like. The gaseous atmosphere can be selected from nitrogen of varying degrees of purity, such as air enriched with nitrogen, a noble gas such as argon, xenon and the like, carbon dioxide and combinations thereof; sea water or other heated water pumped into the ring space and out of the ring space access subunit, and methanol pumped into the ring space and out of the ring space access subunit. Certain hydrate inhibiting fluids include liquid chemicals selected from the group consisting of alcohols and glycols. The flow guarantee fluid can be composed essentially of nitrogen, which means that the gaseous atmosphere comprises nitrogen, can include impurities that do not contribute to the formation or form hydrates themselves and substantially exclude impurities that form or contribute to the formation of hydrates .
[0067] Certain embodiments comprise an external wet insulation adjacent to at least most of the external surface of one or more of wellheads, side valves, casing heads, piping heads, metal forgings, outlet cylinders, suspension and the like. In certain embodiments, the wet insulation comprises a polymeric material. The polymeric material can comprise several layers of polypropylene.
[0068] Certain embodiments of the IVR and the LRA include subunits to allow a functional fluid, such as a flow guarantee fluid, to flow into the internal riser and / or the annular space between the risers and the IVR and LRA orifices. Certain embodiments include subunits to allow the flow of hydrate inhibiting fluid into these spaces. Certain embodiments include subunits for admitting a hydrate remediation fluid in these spaces. Certain embodiments include subunits for admitting fluids for all of these purposes. Once introduced into the internal riser and / or the annular space, the flow guarantee fluid, the hydrate inhibiting fluid and / or the hydrate remediation fluid can stagnate or flow, however mass transfer and thermal transfer favor a flowing fluid.
[0069] Some other embodiments include embodiments in which at least some of the components of the LRA and / or the URA comprise high-strength steel, although the use of steel is not mandatory, and it is possible to use other metals. As used herein, the term “high strength steel” includes steels such as P-110, C-110, Q-125 and C-125 and titanium steels.
[0070] The units described in this document can be used with simple or concentric riser systems. The units described in this document can be used with new wet Christmas trees, including those employing FPSO systems or other floating production systems (FPS), including, among others, semi-submersible platforms. The units described in this document can also be used with new dry trees, including those using compliant towers, TLPs, Spar platforms or other FPSs. The units described in this document can also be used with so-called new hybrid systems (such as TLP or Spar platforms with FPSO or FPS). The units described in this document can be used with risers tensioned by air reservoir systems, hydropneumatic tensioners or combinations thereof.
[0071] These and other characteristics of the systems, apparatus and methods of the present invention will be apparent from reading the brief description of the drawings, the detailed description and the following claims. Brief Description of Drawings
[0072] It will be explained how the objectives of the present invention and other desirable characteristics can be obtained in the following description and in the attached drawings, among which:
[0073] Figures 1, IA and 1B schematically illustrate, Figure IA in detailed cross-section, an embodiment of a riser system in which the units of the present invention can be used;
[0074] Figures 2A and 2B are schematic views in side elevation and in cross section, respectively, of a generic embodiment of a lower riser unit according to the present invention;
[0075] Figures 3A to 3G include several views, some in cross-section, of another embodiment of a lower riser unit according to the present invention;
[0076] Figure 4A is a perspective view, Figure 4B is a cross-sectional view and Figure 4C is a more detailed cross-sectional view of part of the embodiment of the lower riser unit of Figure 3;
[0078] Figures 5A and 5B illustrate schematic views in perspective of another lower riser unit according to the present invention, and Figure 5C is a schematic perspective view of an internal component used in the lower riser unit illustrated in Figures 5A and 5B; Figures 5D and 5E are a cross-sectional view and Figure 5G is a plan view of the lower riser unit shown in Figures 5A and 5B; and Figure 5F is a detailed schematic view of part of the lower riser unit shown in Figure 5E;
[0079] Figure 6 is a schematic side elevation view, with parts removed, of a generic embodiment of an upper riser unit according to the present invention;
Figures 6A to 6G include several views, some in cross-section, of another embodiment of an upper riser unit according to the present invention;
[0081] Figure 6H is a schematic perspective view and Figures 61 and 6J are a cross-sectional view of part of the embodiment of the upper riser unit in Figure 6; Figure 6K is a perspective view of a seal test port;
[0082] Figures 7A and 7B are schematic views in perspective of another embodiment of the upper riser unit according to the present invention;
[0083] Figures 7C and 7D are a cross-sectional view of the embodiment of Figure 7, and Figure 7E is a detailed cross-sectional view of that embodiment; and
[0084] Figures 8A and 8B are schematic illustrations in side elevation and cross section, respectively, of another embodiment of the IVR, while Figures 8C and 8D are schematic illustrations in side elevation and cross section, respectively, of another embodiment of the IVR. LRA according to the present invention.
[0085] It is worth emphasizing, however, that the attached drawings are not faithful to the real proportions and illustrate only typical embodiments of the present invention, and should not, therefore, be interpreted in a way that limits the scope of this invention, since it admits other equally effective embodiments. Same reference numbers are used throughout the various views to identify the same or similar elements. Detailed Description
[0086] In the description that follows, several details are established in order to understand the methods, systems and devices revealed. However, those skilled in the art will realize that the methods, systems and devices can be practiced without these details and that several variations or modifications of the described embodiments are possible. All published United States Patent Applications and United States Patents mentioned in this document, as well as any unpublished United States Patent Applications and non-published literature, are explicitly incorporated into this document by reference. If the definitions of the terms in the aforementioned patents and applications differ from the definition of those same terms in this application, the definitions of those terms presented in this application will be taken as dominant.
[0087] Hereinafter, the main characteristics of various embodiments of the present invention will be described with reference to the Figures in the drawings. Unless otherwise indicated, equal reference numbers are used throughout the Figures in order to indicate the same items in them.
[0088] As already mentioned, submarine units and methods for producing, installing and using them are described, which reduce or overcome many of the defects of previously known submarine units.
[0089] As used in this document, the terms "surface structure" or "surface structure" mean a vessel on the surface or another structure with the function of receiving one or more fluids from one or more self-sufficient risers. In certain embodiments, the surface structure may also include facilities to allow it to perform one or more functions selected from the group consisting of storing, processing and discharging one or more fluids. As used in this document, the term “discharge” includes, among others, combustion (burning) gaseous hydrocarbons. Suitable surface structures include, but are not limited to, one or more vessels, structures that can be partially submerged as semi-submersible structures, floating production and storage structures (FPS), floating storage and discharge structures (FSO), floating production structures, storage and unloading (FPSO), mobile offshore drilling structures such as those known as mobile offshore drilling units (MODUs), Spar platforms, tossing leg platforms (TLPs) and the like.
[0090] As used in this document, the phrase "underwater source" includes, among others: 1) production sources such as underwater wellheads, underwater eruption preventers (BOPs), other underwater risers, underwater manifolds, underwater pipelines and pipelines , underwater storage facilities and the like, whether to produce, transport and / or store gas, liquids or a combination of these, including organic and inorganic materials; 2) underwater containment sources of all types, including BOPs, risers, manifolds, underwater tanks and their leaking or damaged counterparts; and 3) natural sources. Certain embodiments of the system include embodiments in which the containment source is a defective submarine BOP.
[0091] The term “wellhead” is well known in the oil drilling and production technique as a structure with a central orifice and end connectors of various types at both ends, such as junction points, mandrels, toothed locks and their counterparts, which comply with API resistance standards and other parameters for wellheads, as detailed in API specification 6A. As used in this document, the terms “pipe head” and “coating head” are wellheads with relative strength rates such that a pipe head is generally more resistant than a coating head, although it is not always the case. An underwater wellhead can be a pipe head or a casing head, but it is usually a casing head or a structure that is even more resistant due to conditions found on the seabed.
[0092] The terms "flow guarantee" and "flow guarantee fluid" include the guarantee of flow in the presence of hydrates, waxes, asphaltenes and / or crusts already present, and / or the prevention of their formation, and are considered broader than the term “hydrate inhibition”, used in this document to indicate exclusively the prevention of hydrate formation. The term "hydrate remediation" means to remove or decrease the amount of hydrates that have already formed in a given vessel, pipeline or other equipment. The term “functional fluid” includes flow guarantee fluids, as well as fluids that can provide additional or different functions, for example, corrosion resistance, adjustment of the hydrogen ion (pH) concentration, pressure adjustment, density adjustment and their peers, like stopping fluids.
[0093] As used herein, the term "substantially vertical" means at an angle to the vertical direction ranging from about 0 ° to about 45 °, from about 0 ° to about 20 ° or from about 0 ° at about 5o. As such, the term "substantially vertical" includes and is broader than the term "almost vertical" as it is used to describe the angle that the riser will form in relation to the vertical direction.
[0094] Figures 1, IA and 1B schematically illustrate (Figure IA in detailed cross-section) an embodiment of an underwater riser system in which the units described in this document can be used. It will be realized that several subsea riser systems can also benefit from the use of the units described in this document. A self-contained riser (FSR) 2 is shown at an angle α to the vertical direction. The angle α can vary from 0 ° to 90 °, from 0 ° to 45 ° or from 0 ° to 20 ° (considered “almost vertical”). Another angle, β, is defined as the angle between the vertical direction and a line tangent to the flexible conductor 12 near the water surface 20. The angle β can vary from 0 ° to about 90 °, from 0 ° to about 45 ° or from 0 ° to about 20 °. A third angle y, defined as the angle between a chain or other cable 58 (which may be vertical or not) and the end section of a flexible conduit 14 near the base of the FSR, can vary from about 5 ° to about 60 ° or from about 5 ° to about 30 °. It illustrates a stake 16 submerged in the seabed 10, and a chain 58 connects stake 16 to the lower riser unit 8, as we will describe later in this document. Subsea conduit 14 fluidly connects the lower riser unit 8 to a hydrocarbon source, in this case an underwater manifold 26. An upper riser unit 6 fluidly connects riser 2 to a flexible subsea conduit 12, which in turn connects to a vessel on the surface 32. In this embodiment, the upper riser unit 6 also connects to primary 18 and secondary 19 air reservoirs.
[0095] Figure IA illustrates the relative locations of an inner riser 60, a substantially concentric outer riser 70, an outer surface 62 of inner riser 60, an outer surface 72 of outer riser 70, an inner surface 74 of outer riser 70, an annular space 76 and a flow path 64 in the internal riser 60. The solid insulation 80 is adjacent to at least most of the external surface 72 of the external riser 70 and, in certain embodiments, is adjacent to the entire external surface 72 of the riser external 70. In certain embodiments, electrically heated risers may be an option, although, for operational reasons relating to rapid emergency disconnection (QDC) or hurricane evacuation scenarios, this option may not be attractive. Electric heating can significantly complicate the QDC design.
[0096] The circulation of hot air in the annular space 76, or other flow guarantee fluid described in this document, and the insulation of subsea manifolds, flow lines (including flexible subsea ducts 12 and 14 and flexible cables and curved pipes) mentioned in this document) and connectors, in addition to the self-contained riser, can be included in various embodiments. The “circulation” can be continuous or discontinuous. In certain embodiments, the flow-assuring fluid may stagnate after filling the annular space. The possibility of pumping or injecting in some other way one or more flow guarantee fluids in one or more hot stab connectors for ROV is another option, as is the possibility of pumping or injecting in some other way nitrogen or other gas phase in the base of the internal riser or a submarine manifold to the flexible submarine conduits as a way to insert the flow guarantee fluid below a possible or true total or partial hydrate incrustation. In certain embodiments, as shown in the figures, the flow guarantee fluid can be pumped or injected in some other way in various places, for example, among others, at the base of the internal riser 60, at the base of the annular space 76, in the conduit lower flexible (submarine) 14, at the top of the internal riser 60 and annular space 76 and in the upper flexible conduit 12.
[0097] Figure 1B also schematically illustrates a voltage monitoring system 52 on FSR 2. The location of the voltage monitoring system is generally close to the top of FSR 2, although it can be anywhere else on FSR 2, and can understand several of the aforementioned monitoring systems spaced at random or not along the FSR 2. Figure 1B schematically represents a detail of the voltage monitoring system that illustrates a connector 54 and a voltage monitoring module 56. Lower Riser Unit (LRA)
[0098] Figures 2A and 2B are schematic views in side elevation and cross section, respectively, of a generic embodiment of a lower riser unit (LRA) according to the present invention. In this embodiment, the LRA 8 includes a widely cylindrical body CB, an upper end 8UE, a lower end 8LE and five connections Cl, C2, C3, C4 and C5. The Cl connection is a mechanical and fluid connection of the CB cylindrical body to the riser 2. The C4 connection is a mechanical connection of the CB cylindrical body to an underwater anchorage (not shown) by means of a chain or other functional cable 58. The connections C2, C3 and C5 are mechanical and fluid connections of conduits 8A, 8B and 8C with the cylindrical body CB through 8P ports on the cylindrical body CB. Doors 8P extend from an inner surface 81S to an outer surface 8ES of the cylindrical body CB.
[0099] The conduits 8A, 8B and 8C can be, for example, side valve units that connect to subsea hydrocarbon sources, connections to sources of functional fluids, such as flow guarantee fluids, or connections to other subsea equipment or on the surface. Connections C2, C3 and C5 between ports 8P and conduits 8A, 8B and 8C can be threaded connections, flange connections, welded connections or other connections and can be the same or different in terms of the type, diameter and shape of the connection depending on the diameter and shape of 8P doors; for example, 8P doors could have a shape selected from the group consisting of slot, groove, oval, rectangular, triangular, circular and the like. The Cl connection may be a threaded, flange, welded or other connection and may include one or more toothed locks, clamps, split rings or other elements. In certain embodiments, the LRA can connect to manifolds and other equipment, such as flexible tubes, within a 270 ° radius of proximity.
[0100] Figures 3A to 3G illustrate another embodiment of an LRA in several views. Figure 3A is a front elevation view of LRA 8, which, in this embodiment, comprises an external tieback connector 102 connected to an underwater wellhead 104 (as explained later with reference to Figures 4A to 4C) and transition joint 105. In this embodiment, the transition joint 105 is welded, at its upper end, to the base of the subsea well head 104 and, at its lower end, to a base forged piece 106 that includes two machined flange connections 108A and 108B and one look. The machined flange connections 108A and 108B are substantially perpendicular to a longitudinal axis common to the wellhead 104, the transition joint 105 and the forged piece 106, and the machined flange connections 108A and 108B define LRA intake ports. In this embodiment, the base forged piece and the eyebolt constitute a one-piece 106, while the transition joint 105 is a separate piece that connects the base forged piece 106 to the underwater wellhead 104. The transition joint 105 includes a terminal forged piece with eyelet 106, which engages a U-connector 119 and chain 58, which leads to the suction pile unit 16 (not shown).
[0101] The LRA 8 also includes a hot stab panel for ROV 110 in order to operate the external tieback connector 102 to establish the connection with the subsea wellhead 104. The external tieback connector 102 can be a thin line tieback connector or ultrafine, as made available for sale by GE Oil and Gas, Houston, TX (formerly Vetco), EMC Technologies, Inc, Houston, TX, and possibly other suppliers. United States Patent No. 7,537,057 describes such a tieback connector. Those skilled in the art will realize that known external tieback connectors are designed so that, as the structural stress on the connector increases, the permissible bending moment decreases in inverse proportion. Specific curves for these capacity ratios are available from manufacturers.
[0102] A flange 111 connects a curvature restrictor 112 and flexible subsea conduit 14 to a high pressure subsea curvature hindrance 180, which has an internal profile 81 (see Figure 3F) that allows flexible subsea conduit 14 to connect fluidly to the curved unit 107 of the LRA. As Figure 3F schematically illustrates, curvature hinder 180 terminates a flange connection 81 that connects flexible subsea conduit 14 to a high pressure subsea connector 181, which is used for mechanical and fluid connection to conduit 107B of the LRA 8. The curvature hinder 180 removes the moment of the flange connection 81 in order to transfer it directly from the curvature restrictor 112 to the high pressure submarine connector 181, which crosses the upper end of the curvature difficult 180. Containment fluids or production go up the flexible submarine conduit 14 and the flange connection 81, reach a junction unit 116B (two junction units 116A and 116B are indicated in this embodiment) and then cross a production side valve unit 114B in LRA 8 ( two production side valve units 114A and 114B are indicated in this embodiment, Figure 3A).
[0103] As shown in Figures 3A and 3F, each of the production side valve units 114A and 114B comprises respective block elbows 109A and 109B and hand operated valves operated by ROV 115A and 115B, as well as respective flow paths 115C and 115D (figure 3F). Hot stab panels for ROV 150A and 150B, respectively, can be included to monitor temperature and pressure. A submarine clamp structural support 118 supports subsea connectors 119A and 119B (such as those provided by Vector Subsea, Inc. under the trade name OPTIMA). A hot stab panel for ROV 121 installed next to a 116A blanking unit is included, which can accommodate pressure and / or temperature monitoring sensors. In this embodiment, four rotary lifting rings 123 are also included in structural support 118.
[0104] Figure 3C is a detailed view that schematically illustrates hexagon bolts 94 welded at 93 to a retaining bolt retention block 95. Block 95 is also welded at points 97 to the 119B submarine connector body. A similar scheme takes place on the 119A submarine connector, but is not illustrated.
[0105] Figure 3D is a side elevation view and Figure 3E is a plan view of the LRA 8. The curved unit 107 rotates through an extended angle, as may be necessary when connecting the flexible conduit 14, as we can see in plan view, but once connected to connector 119B, this movement is restricted.
[0106] Figure 3F is a sectional view along the dotted line of Figure 3E and illustrates certain internal features of LRA 8, mainly the flow path of the containment or production fluid, as indicated by reference number 113, the path curve 107B (through connector 107A), via 116C, via 115C (via valve 115B and block elbow 109B) and, finally, flow path 64 through internal tieback connector 92 and internal riser 60. Figure 3F also illustrates five casing hangers (sometimes referred to in the confinement hanger technique) 103 pre-installed in the subsea wellhead 104, the topmost hooking hooking the internal tieback connector 92 to the subsea wellhead 104, as explained later with reference to Figures 4A, 4B and 4C. In certain embodiments, there may be one, two, three or more hangers 103. Figure 3G indicates the position of the thermal insulation, indicated by INS, in certain parts of the LRA 8.
[0107] Further details of this LRA embodiment are illustrated in Figures 4A, 4B and 4C, which illustrate the use of two locking hangers 704, 724. In addition to the elements previously detailed, Figures 4A, 4B and 4C illustrate several connecting rods locking indicators 720 that move up and down and indicate whether the external tieback connector 102 is open or completely locked. Also illustrated is one of two secondary mechanical containment plates 702 (the other being hidden in Figure 4A), as well as tubing 110A for the flow of hydraulic fluid through hot stab connectors 110. Hot stab connectors 110 and tubing 110A, running through end cap 110B (or other external ports on connector 102), form part of an upper active locking system 102A for external tieback connector 102. This embodiment also includes a lower passive locking system 102F. Examples of the mechanical details and operation of the upper active locking system 102A and the lower passive locking system 102F are given in United States Patent No. 6,540,024. In short, the upper active locking system 102A comprises an inner sleeve 102C, an axially movable hydraulic piston 102D and an upper locking element 102E, which can be a split ring, clamp or several toothed locks arranged in circumference within a chamber formed between the inner surface of the outer tieback connector 102 and the bottom of the piston 102D.
[0108] Some details of the lower passive locking system 102F of the external tieback connector 102, as well as some details of the internal tieback connector 92, are schematically illustrated in cross section in Figure 4C. Containment hangers 704 and 724 are included, the hanger 704 providing about 0.9 million kgf of confinement capacity in this embodiment. Figure 4C further illustrates the outer body or sleeve 708 and the inner body or mandrel 709 of the inner tieback connector 92. A set of toothed locks 717 is included to lock the casing hanger 704 to the subsea wellhead housing 104. Another set toothed lock 901 is included to lock the external tieback connector 102 to the subsea wellhead housing 104. A lower set of toothed locks 706 locks the sleeve 708 of the internal tieback connector 92 to the coating hanger 704, thereby locking it also to the subsea wellhead housing 104.
[0109] Still with reference to Figure 4C, a similar set of toothed locks 740 locks the internal tieback connector 92 to the tension joint 2FJB and, therefore, to the external tieback connector 102. The lower and upper sets of toothed locks serve as a secondary lock from riser to subsea wellhead 104 and maintain pressure integrity with nasal seal 92A fully engaged if external tieback connector 102 disconnects from subsea wellhead 104 for whatever reason.
[0110] Figure 4C also schematically illustrates hydraulic insulating elements 710, 711 and 715 and a resting surface 712 on an inner part of the coating hanger 704 to rest the nasal seal 92A of the internal tieback connector 92. The hydraulic isolation element 711 includes a wedge 711A that drives the toothed locks 717 to a set of internal matching grooves 717A in the wellhead housing 104. The toothed locks 901 are inserted into a grooved window 902 on the external tieback connector 102. Figure 4C further illustrates a wellhead gasket 716. As those skilled in the art will appreciate, one or more of the toothed locks described in this document can be replaced by a split ring, clamp or other equivalent functional element.
[0111] The internal tieback connector 92 has a nasal seal 92A, which can be of Inconel, which seals to the resting surface 712 in the cover hanger 704. The internal tieback connector 92 engages, by means of toothed locks 706 , both to the coating hanger 704 and to the tension joint 2FJB in order to form a preloaded structural connection between the subsea well head 104 and the internal tieback connectors 102 and external 92 (in addition to the engagement of the external active coupling mechanism with wellhead, so there is multiple redundancy). Nasal seal 92A provides pressure integrity between internal flow path 64 and annular space 76 between internal risers 60 and external 70. Therefore, as shown in Figure 3F, the oil and gas that will be contained or produced cross the duct flexible submarine 14 through a passage defined by the inner surface 113 of the flexible conduit 14, penetrate the side valve unit through passages 107B and 116C and pass through the block elbow 109B and the forgery 106. In this embodiment, with the nasal seal 92A engaged , the produced fluids only have one way to move, which is upwards through the internal riser 60, crossing the passage 64 to the IVR and, finally, crossing the flexible conduit 12 until the containment vessel 32.
[0112] Figures 5A to 5G schematically illustrate another embodiment of a lower riser unit. In this embodiment, a cylindrical member 220 is included, which is a member forged from high-strength steel. The member 220 fluidly connects to a short joint 221 on the production riser by means of a lower intermediate joint 222 and threaded connector 242. A flange with eyelet 223 allows connection of the member 220 with a pile unit on the seabed. Two clamp brackets 224A and 224B support two subsea connectors 225A and 225B, respectively. Two production side valve units 226A and 226B are included, each fluidly connected to member 220 via respective block elbows 230A and 230B. Each 226A, 226B unit includes a ROV operable valve 227A and 227B. An additional unit or subunit 228 is included, which connects fluidly to member 220 via a block elbow 229. The unit or subunit 228 allows fluid connection to a functional fluid source, such as flow guarantee fluid or other fluid. In this embodiment, the block elbow 229 is smaller than the block elbows 230A and 230B, but this need not be so. Another 231 unit is a hot stab unit for injecting a functional fluid. In this embodiment, the hot stab unit 231 enables a lower flow rate of the functional fluid than would be possible by means of unit 228, but, again, this is not necessarily what happens in all embodiments. A smaller diameter duct 241 (figure 5F) allows the functional fluid to be fed.
[0113] Figure 5C illustrates a perspective view of a production pipe or liner 232 that connects to the inner surface of member 220. Production pipe 232 includes a tieback ring 233 and a sealing element 234 that can be an element type S gasket. The sealing element 234 can be made of Inconel or another corrosion resistant metal. As Figures 5D and 5E illustrate schematically, tieback ring 233 includes at least one set of internal threads 235 that matches a set of threads on production pipeline 232. Tieback ring 233 also includes at least one set of external threads 236 that coincides with threads on the inner surface of member 220. Figure 5E illustrates two valves operable by ROV 237A and 237B in line for the injection of functional fluid (or removal) included in the subunit of access to annular space 228, which includes an orifice 238 which gives access to an annular space between the production pipe 232 and the member 220 and lower insert 222. A flange connection 239 or other connection can be included for this purpose. Each production side valve unit 226 includes a connector 240 (240A and 240B) that allows connection to flexible subsea conduits, as shown in the plan view in Figure 5G. Connectors 240A and 240B can be connectors known by the trade name OPTIMA, available from Vector Subsea. Inc.
[0114] Figure 8C is a side elevation view of another LRA unit according to the present invention. This embodiment of the LRA can include a 920 high strength steel forged intake cylinder, a 921 connector and a 944 curved pipe, a 945 submarine API flange, a 946 piping cylinder, a 180 high pressure submarine connector, another API flange submarine 111, a curvature restrictor 112 and a flexible submarine conduit 14 that connects to an underwater hydrocarbon source (not shown). Another connector 947 on the intake cylinder 920 allows connection to a source of functional fluid.
[0115] Figure 8D represents, in cross section indicated by 8D-8D in Figure 8C, details of this LRA embodiment, illustrating an internal tieback connector 92 disposed on the internal surface of the intake cylinder 920. A latching mechanism 930 allows the internal tieback connector 92 connects remotely to the intake cylinder 920, while an O-ring seal 928 establishes a fluid tight seal between the hole of the tieback connector 92 and the ring space 76. The flexible joint 2FJB connects the intake cylinder is known in a known manner, for example, by means of split rings, clamps or toothed locks, as described in this document with reference to other embodiments. Superior Riser Unit (IVR)
[0116] Figure 6 is a schematic side elevation view, with parts removed, of a generic embodiment of an upper riser unit according to the present invention. In this embodiment, the upper riser unit (URA) 6 is a broadly cylindrical member that includes an upper end 6UE and a lower end 6LE and defines an internal orifice 6IB. In this embodiment, the URA 6 shares a common hole with the external riser 70, being able to share more than one common hole with it. Ducts 6A and 6B connect fluidly to the IVR via outlet ports 6OT, conduit 6A fluidly connecting to the internal hole of the internal riser 60, while conduit 6B fluidly connects to an annular space formed by the internal hole 6IB of the IVR with the internal riser 60. The upper end 6UE of the IVR connects to a flotation device close to the surface (not shown) by means of a chain or other connector 127.
[0117] Figures 6A to 6G include several views, some in cross-section, of another embodiment of an upper riser unit according to the present invention. Figure 6H is a schematic perspective view and Figures 61 and 6J are a cross-sectional view of part of the embodiment of the upper riser unit of Figure 6; Figure 6K is a perspective view of a seal test port. In this embodiment, URA 6 includes a piping head 122, which acts as a fluid connection between a casing head unit and stem joint 124, manufactured by GE Oil & Gas, and a drill adapter cylinder 120. The adapter cylinder drill head 120 and pipe head 122 mechanically connect to each other using several confinement units 120A, while pipe head 122 and cladding head and rod joint unit 124 mechanically connect using a second group of confinement units 122B is used. Containment units 120A and 122B may be the same or different and may be confining screw units or other locking units known in the art. A non-limiting example of a confining screw unit is given by United States Patent No. 4,606,557. Also included are an adapter flange for shackle 126, a terminal forged piece with eyebolt 128 and a shackle 125 that allows connection with chain 127. All of these items (except the shackle flange) are available from GE Oil & Gas.
[0118] The pipe head 122 can be machined to a 5-1 / 8 ”and 10 k API flange connection, and the production side valve unit 136 can be connected to a hydraulically operated emergency shut-off valve from 5 in. (13 cm) and 10,000 psi (69 MPa) 137B and a 10,000 psi (69 MPa) ROV operated shut-off valve 131. A panel with ROV hot stab port for monitoring pressure and temperature 139 can be included in certain embodiments, and a ROV panel for injecting nitrogen (or other fluid) 152 can be included in certain embodiments for injecting nitrogen or other gaseous atmosphere into the annular space of the riser. A pipe 158 for injection of nitrogen or other gaseous atmosphere into the annular space can be included in this embodiment, as well as pressure, temperature and bleed ports (through the ROV 153 access panel) between the valves in the production flow path. It is possible to include a rupture disk 156 in the panel for ROV 152. Hot stab ports for ROV and pressure gauges can be included between the two ESD valves in the IVR in order to circulate the functional fluid through the flexible conduit 12 to the surface structure and in order to bleed pressure from the line if necessary (while keeping the first valve closed). An umbilical mounting bracket 155 is included. Several outlet ports 130 can be included in the pipe head 122 (see Figure 6A), as well as several intervention ports 135.
[0119] As shown in Figure 6B, a flange connection 133 can connect a high pressure submarine connector 184 to a curvature restrictor 134. Also included are an initial cylinder 138 and an adapter for curvature restrictor 157. An eye of hoisting 129A can be included to hoist production side valve unit 136, but not when flexible subsea conduit 12 is connected.
[0120] Figure 6D illustrates a side elevation view of IVR 6, and Figure 6E illustrates a cross-sectional view through A-A in Figure 6D. As shown in Figure 6E, an adjustable hanger 159 from the IVR is included in this embodiment. Also indicated is the flow path of the containment fluid, which first rises through the through hole 64, passes through the passage 137D sideways at the block elbow 137A and at the connection 132, passes through a passage 137C on the valve 137B, passes through a passage 131A on the valve 131 and, finally, it leaves the IVR crossing the flow path 184B in the submarine connector 184A, which connects to the flexible conduit 12 through the flange 184C, and the flow path 12A in the flexible conduit 12 until reaching the containment vessel 32 in the marine surface in this embodiment.
[0121] Figure 6F is a plan view of IVR 6 that illustrates in more detail some of the elements previously mentioned. Further details of this embodiment of the IVR are illustrated in Figures 6H to 6K. A 158A nitrogen injection port is illustrated, as well as a bottom part 122A of the pipe head 122, which includes a seal test port 718. A seal ring 720 between the pipe head 122 and the coating head 124; a metal-to-metal seal 722; a torque tool profile 724, a cross connection 726 and a load ring to support the hanger 728, as well as a hydraulic isolation element 730. Figure 6J further illustrates a forged part 734 of the IVR with ports 732 suitable for connecting it pressure and temperature meters. Finally, a sealing ring 736 is illustrated between the drill adapter cylinder 120 and the tubing head 122. Figures 6H and 61 illustrate that the casing head and stem joint unit 124 comprises a lower part 124A of the head lining and a rod joint 124B welded in 124C to the bottom 124A of the lining head.
[0122] Figure 6G is a schematic perspective view of URA 6, which illustrates the location of the insulating material, INS, around valves 137B and 131, as well as around related pipes.
[0123] Figures 7A and 7B are schematic views in perspective of another embodiment of the upper riser unit (URA) according to the present invention, Figures 7C and 7D are a cross-section of the embodiment in Figures 7A and 7B, and Figure 7E is a detailed cross-sectional view of part of this embodiment. This embodiment of the IVR is different from that illustrated in Figures 6A to 6K mainly because it allows the circulation of a functional fluid, such as heated water, through the annular space. The IVR embodiment schematically illustrated in Figures 7A to 7E replaces two of the large side valves and large diameter passages of the embodiment illustrated schematically in Figures 6A to 6K by the ROV connection functionality for injecting a functional fluid, such as nitrogen. In the embodiment shown in Figures 7A to 7E, another flexible conduit (not shown for clarity) can connect to the IVR via an underwater connector 818 and extend to a vessel on the surface whether continuous or semi-continuous circulation in space ring or through it is desired.
[0124] An output cylinder 804 connects fluidly to a suspension cylinder 803. In this embodiment, the suspension cylinder, in turn, connects to a tapered voltage joint 802, which is not part of the IVR in itself, but is illustrated for completeness and to demonstrate how the IVR connects to a riser system. A shackle 806 and chain 807 allow the IVR to mechanically connect to a flotation device close to the surface (not shown). As Figure 7D best illustrates, the block elbow 808 includes an inner hole 808A that intersects a hole 804A in the outlet cylinder 804 and is substantially perpendicular to it. This embodiment also includes a block elbow 809 and internal orifice 809A substantially perpendicular to orifice 804A, but which does not intersect with it.
[0125] A curved conduit 810 provides, in the embodiments, a flow path for hydrocarbons together with the orifice in the elbow 808A, the first emergency shut-off valve (ESD) 811 and the second ESD 812 valve. An 813 outlet on connector 813A it can be connected to a flexible underwater conduit 12 for production or containment operations. The 813A connector may be a connector known by the trade name OPTIMA or another connector suitable for subsea use. A connection is made to ROV 814 for the operation of connector 813A. A bleed valve 815 can also be included, which acts to allow stoppage in the IVR, bleed contents from the curved conduit 810 and recover the flexible submarine conduit, for example, in the event of a hurricane or planned or unplanned event.
[0126] Valves 816 and 817 are included for circulation and / or production and / or injection of functional fluid through connector 818. Valves 816 and 817 can be operated by ROV. A functional fluid can also be injected into the annular space using another valve operable by ROV 819 and connector 820, which can be a flange connector.
[0127] Figure 7E is a detailed cross-sectional view of the area where outlet cylinder 804 and suspension cylinder 803 connect. Two seal ring and wire retainer structures 822 establish two seals between the fluid that passes through hole 825A in piping 825 and chamber 827 that holds shims 824. A passageway 826, which allows access to structures 822, can also be included.
[0128] Figure 8A schematically illustrates in lateral elevation another embodiment of an upper riser unit according to the present invention. The IVR 6 includes, in some embodiments, an outlet cylinder with a production orifice 910 fluidly connected to a conduit 911 and a production pipeline 913. The production pipeline 913 is connected fluidly to a curvature restrictor 134 by means of one submarine API flange 905, one high pressure submarine connector 184, another submarine API flange connection 133 and, optionally, a submarine connector (such as the one provided by Vector Subsea, Inc. under the trade name OPTIMA). The curvature restrictor 134 can connect to a flexible submarine conduit 12, which extends in catenary in a known manner to a structure on the surface. In this embodiment, an ESD valve 915 is included in the pipe section 911, which can be operated by ROV. In this embodiment, an angled support 916 is included, which, in addition to supporting tubing 913 at an angle o, also supports a bulkhead against bending 942, which serves as a mechanical barrier between the side units. The angle o can vary from 0 ° to about 180 °, from about 30 ° to about 90 ° or from about 30 ° to about 45 °. Piping 911 connects seamlessly to an adapter 926, which in turn connects seamlessly to a suspension cylinder 912 via an API 917 flange, to a casing head 124 via another API 918 flange, to a stem joint 124B welded to a casing head 124 and to a riser 2 screwed onto the stem joint 124B. The outlet cylinder 910 may include a flange with shackle 127 that allows connection with a chain 125 and a flotation device close to the surface (not shown).
[0129] Another feature of this embodiment, illustrated in Figure 8A, is the inclusion of a connector 906 in the suspension cylinder 912 to connect to a curved pipe 907, an API 908 flange, a pipe 909, a high pressure underwater connection 940 , another submarine API flange 941 and a curvature restrictor 923 connected to a flexible submarine conduit 919 to feed heated water (or other flow guarantee flow) to the suspension cylinder 912 from a surface structure. The heated water (or other flow guarantee fluid) can then descend through the annular space towards the LRA and leave the annular space through one or more sub-valves to access the annular space, such as those indicated by 142 and 144 in Figure 8C.
[0130] Figure 8B illustrates, in cross section indicated by 8B-8B in Figure 8A, details of this embodiment of the IVR. An internal riser 60 is illustrated inside the adapter 926, the suspension cylinder 912 and the coating head 124, thus forming an annular space 76 between the inner surface 912A of the suspension cylinder 912 and the internal riser 60. In this embodiment, a pair of O-ring seals 925 seals inner riser 60 to adapter 926. One or more shims 924 are arranged between an inner inclined surface 943 on suspension cylinder 912 and inner riser 60, thereby securely securing inner riser 60 to the suspension cylinder 912.
[0131] Figure 8C is a side elevation view of another LRA unit according to the present invention. This embodiment of the LRA includes a 920 high strength steel forged intake cylinder, a 921 connector and a 944 curved pipe, a 945 subsea API flange, a 946 tubing cylinder, a 180 high-pressure subsea connector, another subsea API flange 111, a curvature restrictor 112 and a flexible subsea conduit 14 that connects to an underwater hydrocarbon source (not shown). Another connector 947 on the intake cylinder 920 allows connection to a source of functional fluid.
[0132] Figure 8D represents, in cross section indicated by 8D-8D in Figure 8C, details of this LRA embodiment, illustrating an internal tieback connector 92 disposed on the internal surface of the intake cylinder 920. A latching mechanism 930 allows the internal tieback connector 92 connects remotely to the intake cylinder 920, while an O-ring seal 928 establishes a fluid tight seal between the hole of the tieback connector 92 and the ring space 76. The flexible joint 2FJB connects the intake cylinder is known in a known manner, for example, by means of split rings, clamps or toothed locks, as described in this document with reference to other embodiments.
[0133] Flow assurance calculations can indicate whether an FSR can be designed with a 5-layer, 3-in. Polypropylene thermal insulating coating. (7.6 cm) thick applied to the external riser, while the annular space between the internal and external risers would be filled with low pressure nitrogen. During operation, this scheme can substantially maintain the temperature of hydrocarbons from the underwater source to the surface structure. Materials, Construction and Installation Methods
[0134] In addition to gaskets, hoses, flexible ducts and other components that are not considered part of the present invention, the main components of the LRAs and IVRs described in this document (exit cylinders, intake cylinders, suspension cylinders, largely cylindrical members, riser sections, tubing heads, casing heads, tubing cylinders, subsea high pressure connectors, rod joints, riser tension joints and the like) can be made primarily of steel alloys. Although low alloyed steels can be used in certain embodiments in which the water depth is no more than a few thousand feet, activities in waters of greater depth, with wells reaching 20,000 feet (6,000 meters) and beyond, can result in temperatures and above normal operating pressures. In these “high temperature and high pressure” (HPHT) applications, the metallurgy of low-alloy and high-strength steels such as C-10 steel and C-125 steel may be more suitable.
[0135] Research Partnership to Secure Energy for America (RPSEA) and Deepstar initiated a large-scale, long-term prequalification program to develop fatigue databases and derive degradation factors for high-strength materials in applications riser with the contribution of renowned operators, engineering companies and material suppliers. High strength steels (such as X-100, Cl 10, Q-125, C-125, V-140), titanium (such as grade 29 and possibly newer alloys) and other possible candidates for material in the high strength category may be tested in piping applications and, depending on the results, be used as material in risers, LRAs and IVRs as described in this document. High strength forging materials (such as F22, 4330M, Inconel 718 and Inconel 725) have already been or will be tested soon as components in applications in the coming years and may prove useful as one or more components of the LRA and / or URA units and / or risers described. The test matrix can be designed to reproduce various production environments and different types of riser configurations such as simple catenary risers (SCRs), dry Christmas tree risers and drilling and completion risers. Currently, the project is scheduled to be divided into 3 distinct phases. Phase 1 will analyze the tensile and fracture resistance, FCGR and SN tests (both smooth and chamfered) on strip samples of high strength pipes, high strength forging materials and forged nickel alloy forgings in the atmosphere, in seawater, in seawater with cathodic protection (CP) and in hostile environments (not inhibited) and a completion fluid known as INSULGEL (BJ Services Company, USA) with contamination from hostile environments (not inhibited) (2008 ). Phase 2 is scheduled to be the Intermediate Scale Test (2009) and phase 3 the Full Scale Test with H2S / CO2 / seawater (2010). For more information, see Shilling et al., “Development of Fatigue Resistant Heavy Wall riser Connectors for Deepwater HPHT Dry Tree riser Systems”, OMAE (2009) 79518 (copyright 2009 ASME). See also RPSEA RFP2007DW1403, “Fatigue Performance of High Strength Riser Materials”, November 28, 2007. Those skilled in the art, with knowledge of the depth, pressure, temperature and specific materials available, can design a system for each specific application without experimentation. improper.
[0136] In recent years, the holder of this invention has participated in the development of a comprehensive qualification program for dry Christmas tree risers of 15/20 ksi (103/138 Mpa) with an emphasis on demonstrating the convenience of using materials of high strength steel and specially designed threaded and coupled connections (T&C) machined directly at the riser joints in the mill. See Shilling et al., “Development of Fatigue Resistant Heavy Wall riser Connectors for Deepwater HPHT Dry Tree riser Systems”, OMAE2009-79518. These connections can eliminate the need for welding and facilitate the use of high-strength materials such as NACE-qualified C-110 and C-125 metallurgies. (As used in this document, “NACE” refers to the corrosion prevention organization, formerly known as the National Association of Corrosion Engineers, now operating under the name NACE International, Houston, Texas.)
[0137] The use of high-strength steel and other high-strength materials can limit the required wall thickness, allowing you to design riser systems that resist pressures much greater than can be supported by X-80 materials and install them at much greater depths of water due to less weight and therefore less stress conditions. T&C connections can reduce the need for third-party forging and costly welding processes, greatly improving delivery time and total system cost. Using these materials and connectors to design a fully qualified second generation 16 ksi (103/138 MPa) FSR containment system, the external riser can be truly reduced in size by 13.813 inches. (35,085 cm) outside diameter to 10.75 in. (27.305 cm) external diameter x 0.75 in. (1.91 cm) wall thickness with a 7-inch C-110 internal riser. (17.8 cm) outside diameter x 0.453 in. (1.15 cm) wall thickness. It will be realized, however, that the use of third party forging and welding is not out of the question for the IVRs, LRAs and risers described in this document and may, in fact, be preferable in certain situations. Those skilled in the art, with knowledge of the depth, pressure, temperature and specific materials available, can design a system for each specific application without undue experimentation.
[0138] Connections of units described in this document with risers and connections within units, such as connections from the drill adapter cylinder to the piping head, connections of substantially cylindrical members to risers and the like, may include threading, as described in aforementioned article by Shilling et al., as well as described in the following patent documents: W02005 / 093309, W02005 / 059422 and United States Patents 6,752,436 and 6,729,658. Further information can be found in the following publications: Sches et al., “Fatigue Resistant Threaded and Coupled Connectors: the New Standard for Deep Water riser Applications”, OMAE 2007-29263; Sches et al., “Fatigue Resistant Threaded and Coupled Connectors for Deepwater riser Systems: Design and Performance Evaluation by Analysis and Full Scale Tests”, OMAE 2008-57603; and Shilling et al., “Developments in Riser Technology for the Next Generation Ultra-Deep HPHT Wells”, DOT Conference, 2008 Proceedings.
[0139] The materials for the construction of gaskets, flexible ducts and hoses used with the units and methods described in this document will depend on the specific depth, temperature and water pressure to which the units will be subjected. Although it is possible to use elastomeric gaskets in certain situations, metallic gaskets have been increasingly used in subsea applications. For analysis of the technique around 1992, see Milberger et al., "Evolution of Metal Seal Principies and Their Application in Subsea Drilling and Production", OTC-6994, Offshore Technology Conference, Houston, Texas, 1992. See also standard 601 from API: “Standard for Metallic Gaskets for Raised-face Pipe Flanges & Flanged Connections and API Spec 6A - Specification for Wellhead and Christmas Tree Equipment”.
[0140] The gaskets themselves are not part of the units and methods of the present invention, but, as certain embodiments of LRA and URA may employ gaskets (such as the 716 gasket in the wellhead mentioned with reference to the LRA embodiment in Figure 3J) , we mention the following United States Patents, which describe gaskets that may be suitable for use in specific embodiments: United States Patents 3,637,223, 3,918,485, 4,597,448, 4,294,477 and 7,467,663. In certain embodiments, the gasket material known as the DX gasket, qualified for 20 ksi, can be used.
[0141] Another gasket that can be used on the seabed is the one known by the trade name of Pikotek VCS, available from Pikotek, Inc., Wheat Ridge, Colorado (USA). This type of gasket is believed to be described in United States Patent 4,776,600, incorporated by reference to this document.
[0142] In certain embodiments, the IVR may have a recoverable rupture disk, allowing the IVR to be connected to the atmosphere. In certain embodiments, that rupture disc can be a recoverable rupture disc. The rupture discs can allow, among other things, to ventilate the annular space above the LRA and, in certain embodiments, allow the pumping of a functional fluid, such as nitrogen, to the annular space near the top of the FSR. The rupture discs can be used to measure the pressure and / or temperature of the flow of flow (inside the internal riser) or in the annular space between the internal and external risers. In addition to rupture discs, hot stab connectors for intense flow can be used in various types of equipment, for example, in emergency disconnection systems.
[0143] Flexible underwater pipelines, sometimes referred to in this document simply as "flexible pipelines" or "flexible cables", are familiar to those skilled in the underwater drilling and hydrocarbon production technique. For example, United States Patent No. 6,039,083 discloses that flexible conduits are often used to transport liquids and gases between submerged pipelines and oil and gas production facilities, as well as other offshore facilities. These ducts are subjected to high internal and external pressures, as well as to chemical actions associated with the sea water that surrounds the submerged ducts and the fluids transported within them. United States Patent No. 6,263,982 discloses flexible subsea ducts that comprise flexible steel ducts such as those manufactured by Coflexip International of France under the trade name “COFLEXIP”, such as the 5 ”flexible duct. (12.7 cm) internal diameter, or shorter segments of rigid ducts connected by flexible joints and other flexible ducts known to those skilled in the art. Other patents of interest, on behalf of Coflexip and / or Coflexip International, include United States Patents 6,282,933, 6,067,829, 6,401,760, 6,016,847, 6,053,213 and 5,514,312. Other potentially useful flexible conduits are described in United States Patent No. 7,770,603, in the name of Technip, Paris, France. United States Patent No. 7,445,030, also in the name of Technip, describes a flexible tubular duct that comprises successive independent layers with coils of different strips or sections and at least one polymeric lining. At least one of the cylinders includes one or more strips of polytetrafluoroethylene (PTFE). This list is not intended to include all flexible conduits that can be used in the systems and methods of the present invention.
[0144] The hoses, also referred to in this document as flexible cables in certain embodiments, suitable for use with the systems and methods of the present invention can be selected from various materials or combinations of materials suitable for use on the seabed; in other words, with high temperature resistance, high chemical resistance and low permeation rates. Some fluoropolymers and nylon are particularly suitable for this application, except in the case of extremely long ducts (several kilometers or more), in which permeation can be problematic. Good research on hoses and materials can be found in United States Patent No. 6,901,968, currently in the name of Oceaneering International Services, London, Great Britain, which describes the so-called “high collapse resistant hoses” of the type used in applications on the seabed, which, in use, resist collapse due to very high pressures exerted on them.
[0145] In certain embodiments, it may be necessary or desirable to join one hose to another or replace a damaged hose. In such cases, it is possible to use the devices for joining ROV-operable hoses described in the serial number orders 61.479.486 and 61.479.489, both deposited on April 27, 2011 in the name of the holder of this invention. Order 61.479.486 describes devices for connecting ROV-operated hydraulic hoses, whereas order 61.479.489 describes devices for connecting non-hydraulic (mechanical) hoses that are operable by ROV. Each device includes a through-hole connector while allowing full-pressure service that can be preferred in applications that require high flow rates and high pressure. A simple penetration movement, which uses a funnel, minimizes the necessary skill on the part of the ROV pilot. Hydraulic devices include at least two chambers and at least one self-locking mechanical lock per chamber, in which, after a hose enters a chamber, the ROV pilot feeds energy to the device, the connection is established without the need to move ROV manipulators, and hydraulic pressure can be released from the chambers. A hot stab connector for ROV can be used in certain embodiments to connect the device to a hydraulic ROV power unit in order to supply power and operate the device.
[0146] The units described in this document can be used with a simple duct (single line displaced riser - SLOR) or with a duct in duct design (concentric displaced riser - COR) that provides additional insulation and allows the rise of base or active heating through the annular space. These risers can be welded or threaded and can be tensioned by an upper air reservoir located 50 to 150 m below the surface depending on environmental conditions, by hydropneumatic tensioners or both. Each self-contained riser can connect to the surface structure (for example, a surface vessel or a production platform) via a flexible cable for shallow water.
[0147] In certain embodiments, the riser voltage is maintained using a separate air reservoir system connected by currents above the riser column. Air reservoirs provide the necessary float pull for overall stability and movement performance control, and ensure that the effective tension of 100 kip (45,000 kg) is exerted on the riser base in all load conditions, including failure one or more chambers of the air reservoirs. In one embodiment, an LRA manufactured largely in accordance with Figures 3 and 4 weighs about 30 kip (13,600 kg) in the atmosphere and 26 kpis (11,800 kg) when submerged. It can be connected to the suction stake by 90 feet (27 meters) of a 117 mm R-4 prisoner chain with a break resistance of 2,915 kip (1,300,000 kg) and a 250 ton Crosby G-2140 shackle (230,000 kg) with a breaking strength of 2,750 kip (1,230,000 kg). In this embodiment, the LRA comprises a 15 ksi (103 MPa) H-4 underwater wellhead from GE Oil & Gas (Vetco), specially machined at 2 x 7-1 / 6 inch inlets. (5.08 x 18.2 cm) and 10,000 psi (69 MPa) to accommodate either multiple cable connections or, as shown in Figure 3, a production cable and an ROV interface for methanol injection.
[0148] The concept of containment or production with FSR using the units disclosed in this document is adaptable to a wide range of water depths and well pressures and conditions. Flow assurance calculations indicate that the FSRs, LRA and IVR used are capable of handling more than 40,000 barrels per day (6,400 m3 / day), each with a 6-inch flow path. (15 cm) of internal diameter. Existing readily available dry Christmas tree riser hardware can be used to build the FSRs. The joints of the external riser can be of material X-80 with 13,813 in. (35,085 cm) outside diameter x 0.563 in. (1.43 cm) wall thickness and qualified for 6,500 psi (45 MPa). The X-80 material can be used for welding special riser connectors with metal-to-metal external and internal seals and fatigue performance for the expected service life.
[0149] Riser systems employing the URA and / or LRA units of the present invention can be installed, in certain embodiments by a MODU, and then accommodate the installation of upper flexible cables after installation of the riser. The upper flexible conduit can be connected to the IVR during installation by the drilling MODU and, optionally, be fixed at intervals that hang vertically along the riser. The lower flexible underwater duct can be connected several days later to the LRA by vessels of subsea installation after connecting and fractionating the FSR to the suction pile.
[0150] The structure on the surface can be equipped with a quick disconnect system (QDC) for the upper flexible conduit. Embodiments of a quick connect / disconnect shackle element are described in the United States provisional order on behalf of the serial number holder 61.480.368, filed on April 28, 2011. A disconnectable float can be used to support the end on the surface structure of the upper flexible conduit in the event of an emergency disconnection. The float can be connected to provide both buoyancy and drag and to ensure that the upper flexible conduit does not become damaged due to too fast descent (ie, by excessive compression greater than the minimum radius of curvature) after being released for free fall. In the event of a hurricane or planned disconnection, the 6 ”upper flexible conduit. (15 cm) disconnects from the structure on the surface in a controlled manner and is lowered by a support vessel to hover along the side of the FSR, where it is fixed in place by an ROV.
[0151] In certain concentric riser embodiments in which one or more of the LRAs and / or IVRs described in this document can be used, the IVR can allow flow control of both the internal riser and the annular space between the internal and external risers. The flow path in the internal riser may have provisions for pressure and temperature sensors; a hydraulically driven ESD valve that closes in the event of a controlled failure from the structure on the surface; a hot stab pressure bleed port for ROV; and / or a hand operated valve operated by ROV. The annular space can incorporate provisions for the injection of nitrogen by hot stab connection with ROV and a temperature and pressure sensor. A pressure safety valve (PSV) set to 4,500 psi (31 MPa) in the annular space of the riser can prevent failure due to excess pressure from the external riser in the event of hydrocarbon leakage from the internal riser.
[0152] In certain embodiments, the LRA provides hot stab access via ROV to both the annular space of the riser and the production flow path for monitoring injection, ventilation, pressure and temperature. Two 3-inch valves (7.5 cm) operated by ROV in the ring space access subunit provide a larger ring space access hole for nitrogen disposal and ventilation or other functional operations. In certain embodiments, the LRA flow path is formed by two cylinders, each equipped with a 5 "ROV operated valve. (13 cm) and 10 ksi (69 MPa) and clamp units operated by ROV (such as those provided by Vector Subsea) for the underwater connection of flexible production cables.
[0153] In certain embodiments, the LRA and URA units described in this document can be used as components of a production or containment and disposal system. In this case, a hydrate inhibition system (HIS) can be integrated into the systems and methods. Lines for feeding hydrate inhibiting chemicals from the vessel on the surface can feed chemicals to the lid of a submarine drawer BOP, to a BOP and to flexible submarine ducts through a submarine manifold. When circulating the chemical, it can return to the vessel via a return line. The chemical can be fed into obstruction lines or plugging the submarine BOP through an obstruction / plugging manifold.
[0154] By reading the detailed description above of specific embodiments, the description of the patented units and methods appears. Although we have described specific embodiments of the invention in some detail in this document, we have done so only in order to describe various characteristics and aspects of the units and methods without the intention of limiting their scope. It is contemplated that various substitutions, alterations and / or modifications, including, among others, variations in implementation that may have been suggested in this document, are carried out to the described embodiments without departing from the scope of the appended Claims.

权利要求:
Claims (31)
[0001]
1 - Upper Riser Unit To Connect Submarine Riser, (2), the Submarine Flotation Device and the Surface Structure, comprising: a cylindrical outer member (6) with a longitudinal hole (61B), a lower end (6LE), an upper end (6UE) and a cylindrical outer surface where the upper end of the outer member (6) comprises a connector (127) configured to connect the outer member (6) to a subsea flotation device, and where the lower end (6LE) of the external member (6) is coupled to an upper end of an external riser (70); a cylindrical inner member disposed within the outer member (6), in which the inner member has a longitudinal production hole, a lower end, an upper end and a cylindrical outer surface, in which the lower end of the inner member is coupled to a upper end of an internal riser (60), where the internal riser (60) is arranged concentrically within the external riser (70); an annular space (76) disposed between the internal riser (60) and the external riser (70); and an outlet port extending from the production port of the inner member to the cylindrical outer surface of the outer member (6), wherein the outlet port is fluidly coupled to a wing valve production assembly (136) and is configured to flow hydrocarbons from the internal riser (60) to the surface structure with a submarine flexible conduit (12); characterized in that: a plurality of inlet holes extend from the outer cylindrical surface of the outer member (6) to the orifice of the outer member (6), wherein each of the plurality of inlet holes is configured to circulate a functional fluid through the annular space (76) between the internal riser (60) and the external riser (70).
[0002]
2 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 1, characterized by the fact that the outer member (6) comprises a drilling adapter cylinder (120), a tubing head (122) attached to the drill adapter cylinder (120) and a casing head attached to tubing heads, where the outlet port (130) extends through the tubing head (122) , and wherein the plurality of entrance doors extend through the casing head.
[0003]
3 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 2, characterized by the fact that the casing head includes a rod joint (124) connects to the upper end of the external riser (70).
[0004]
4 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 3, further comprising an adjustable pipe hanger (159) disposed inside the pipe head ( 122), characterized in that the adjustable pipe hanger (159) has a lower end connected to an upper end of the internal riser (60).
[0005]
5 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 4, characterized by the fact that the production side valve unit (136) comprises valves flow control first and second (131, 137B) configured to control the flow of hydrocarbons through the submarine flexible conduit (12).
[0006]
6 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 1, characterized by the fact that the production side valve unit (136) comprises a or more ROV hot stab ports (139, 152) configured for a flow of a guarantee fluid in the internal riser (60) and in the annular space (76) between the internal riser (60) and an external riser (70), in that the guarantee fluid flow is selected from the group consisting of nitrogen or other gaseous phase, sea water or other heated water and organic chemicals.
[0007]
7 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 1, characterized by the fact that the outer member (6) comprises an outlet cylinder ( 804), a shackle flange (127) connected to the outlet cylinder (804) and a suspension cylinder (803) connected to the outlet cylinder (804), in which the outlet cylinder (804) and the suspension cylinder (803) ) define the longitudinal hole of the external member (6).
[0008]
8 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 7, characterized by the fact that the outlet cylinder (804) comprises an orifice (808A ) oriented perpendicular to the longitudinal hole (804A), where the hole (808A) of the outlet cylinder (804) defines the outlet port (130).
[0009]
9 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 8, characterized by the fact that the production side valve unit (136) comprises a curved duct (810) and two emergency shut-off valves (ESD) (811, 812) arranged along the curved duct (810), where a first of the ESDs is configured to be hydraulically driven and a second of the ESDs is configured to be electronically triggered.
[0010]
10 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 7, characterized by the fact that the suspension cylinder (803) comprises an orifice (809A ) oriented perpendicular to the longitudinal orifice (804A), where the orifice (809A) of the suspension cylinder (803) is in fluid communication with the annular space (76), and where a valve unit for access to the annular space (816 .817) is configured to control the flow of fluids through the orifice (809A) of the suspension cylinder (803).
[0011]
11 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 10, characterized by the fact that the ring space access valve unit (816, 817) comprises one or more ROV-operable valves (819).
[0012]
12 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 11, characterized by the fact that the valve unit for access to the annular space (816, 817) fluidly connects to a flow guarantee fluid source.
[0013]
13 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 1, characterized in that the external member (6) comprises an outlet cylinder with production line (910) and a vertical duct (011) coupled to the output cylinder with a production port (910); where the outlet port is in fluid communication with a production pipeline, which is coupled to a curvature restrictor (134) by means of a submarine API flange (90S), a high pressure submarine connector (184), and another submarine API flange connection (133), in which the curvature restrictor (134) is coupled to the flexible submarine conduit (12); and where the vertical duct (911) connects seamlessly in series to an adapter (926), which in turn connects seamlessly to a suspension cylinder (912), an API flange (917), to a casing head (124) by means of another API flange (918), to a rod joint (124B) welded to the casing head (124) and to the external riser (70) by means of a threaded connection with rod joint ( 124B), wherein the outlet cylinder (910) includes a shackle flange (127) configured to connect with the subsea flotation device.
[0014]
14 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 13, characterized by further comprising an ROV-operable ESD valve (915) fluidly connected to a conduit section (911).
[0015]
15 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 14, characterized by also comprising an angular support (916) that supports the production pipe ( 913) at an angle o of the duct (911) and which also supports a bulkhead (942) that provides a mechanical barrier between the production pipe (913) and the duct (911), where the angle varies from 0 to 180 °.
[0016]
16 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 15, characterized by further comprising a connector on the suspension cylinder (912) to connect to a curved pipe (907) for feeding heated water to the suspension cylinder (912) from a vessel on the surface.
[0017]
17 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 16, characterized by the fact that the curved pipe (907) comprises, in the order starting at suspension cylinder (912), an API flange (908), a pipe section (909), a submarine high pressure connector (940), an API connector (940) and submarine API flange (941) and a curvature restrictor (923).
[0018]
18 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 17, characterized by the fact that the internal riser (60) is arranged inside the adapter ( 926), the suspension cylinder (912) and the coating head (124), in which an annular space (76) the suspension cylinder (912) and the internal riser (60) are in fluid communication with the annular space ( 76) between the internal riser (60) and the external riser (70).
[0019]
19 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 1, characterized by comprising components configured to circulate a functional fluid through the annular space (76 ).
[0020]
20 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 19, characterized in that the outer member comprises an outlet cylinder (804) coupled to a suspension cylinder (803), where the suspension cylinder (803) is coupled to an inclined tension joint (802) of the self-supporting riser (2).
[0021]
21 - Upper Riser Unit for Connecting Submarine Riser, (2), the Submarine Flotation Device and the Surface Structure, according to Claim 20, characterized by further comprising a first block elbow (808) comprising an internal hole ( 804) which intersects with and is oriented perpendicular to the longitudinal hole (804A), a second block elbow (809) with an internal hole (809A) oriented perpendicular to the longitudinal hole (804A), but which does not intersect with it, and a curved conduit (810) fluidly connected to the first block elbow (808), thus establishing a flow path for hydrocarbons together with the internal hole (809A) of the first block elbow (808).
[0022]
22 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 21, further comprising a first emergency shut-off valve (811) and a second emergency closure (812) in the curved conduit (810), characterized in that the curved conduit (810) is in fluid communication with the flexible underwater conduit (12).
[0023]
23 - Upper Riser Unit For Connecting Submarine Riser, (2), Submarine Flotation Device and Surface Structure, according to Claim 19, characterized by the fact that the components that allow the circulation of a functional fluid through the annular space (76) comprises a submarine connector (818), a conduit and one or more valves (816, 817) in the conduit, which connects fluidly to the suspension cylinder (803).
[0024]
24 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, the submarine riser system comprising: a concentric stand-alone riser (2) comprising an internal riser (60) disposed inside an external riser (70 ) and having an annular space (76) between the internal riser (60) and the external riser (70); the upper riser assembly, as defined in Claim 1, coupled to an upper end of the concentric independent riser (2), characterized in that the lower end (6LE) of the cylindrical member (6) is coupled to an upper end of the external riser (70 ); and a lower riser assembly coupled to a lower end of the concentric stand-alone riser (2); wherein the lower riser unit comprises: a cylindrical member (CB) of the lower riser unit (CB) with a longitudinal hole, a lower end (8LE), an upper end (8UE) and a cylindrical outer surface, comprising the member cylindrical (CB) of the lower riser unit (CB) a number of intake ports (108A / 108B) that extend from the outer surface to the orifice sufficient to accommodate the flow of hydrocarbons from the fluid hydrocarbon source, as well as the inflow of a functional fluid, at least one of the intake ports (108A, 108B) fluidly connected to a production side valve unit (114A, 114B), having the upper end (8UE) of the cylindrical member (CB) of the lower riser unit (CB) a profile suitable for fluidly coupling to the upper end of the concentric stand-alone riser (2), and the lower end (8LE) of the cylindrical member (CB) of the lower riser unit (CB) having a suitable connector for connect to an anchorage on the seabed.
[0025]
25 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, according to Claim 24, characterized by the fact that the cylindrical member (CB) of the lower riser unit (CB) of the lower riser unit comprises: an underwater wellhead housing (104) whose lower end is modified by connecting a transition joint (105) to it, the transition joint comprising said sufficient number of intake ports (108A, 108B), the end top of the subsea wellhead housing (104) fluidly connected to an external tieback connector (102), which fluidly connects the subsea wellhead housing (104) to a riser tension joint (2FJB), having the housing subsea wellhead (104) an internal sealing profile adapted to seal an internal tieback connector (92), which fluidly connects an internal subsea riser (60) to the internal sealing profile, and having the internal tieback connector (92) a nasal seal (92A) that seals to the underwater wellhead profile, providing the nasal seal (92A) pressure integrity between an internal flow path (64) in the internal riser (60) and an annular space (76) between the internal riser (60) and an external concentric riser (70) (70).
[0026]
26 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, according to Claim 25, characterized in that the production side valve unit (114A, 114B) of the lower riser unit connects fluidly to an underwater source through a flexible underwater conduit (14).
[0027]
27 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, according to Claim 25, characterized by the fact that the riser voltage joint (2FJB) connects fluidly to the external riser (70).
[0028]
28 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, according to Claim 25, characterized by still comprising valves operated by ROV (115A, 115B) to control the flow through the internal flow path ( 64) in the internal riser (60) and in the annular space (76).
[0029]
29 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, according to Claim 25, characterized by still comprising one or more hot stab doors (150A, 150B) for ROV intervention and / or maintenance.
[0030]
30 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure, according to Claim 24, characterized by the fact that: the cylindrical member (CB) of the lower riser unit comprises a metal forged part of high strength (220) fluidly connected to a short joint of the production riser (221) by means of a lower interlayer joint (222) and a threaded connector (242), the forged part (220) comprising said longitudinal hole, said lower end, said upper end, said cylindrical outer surface and said sufficient number of intake ports (108A / 108B) of the lower riser unit, the lower end of the metal forgings (220) comprising the connector (223) suitable for connecting to the undersea anchorage.
[0031]
31 - Submarine Riser System Connecting a Submarine Hydrocarbon Fluid Source to a Surface Structure according to Claim 24, characterized in that the cylindrical member (CB) of the lower riser unit comprises an intake cylinder (920) forged from high-strength steel fluidly connected to a curved unit (944), which fluidly connects to an underwater source via a flexible underwater conduit (14), the intake cylinder (920) further comprising a connector (947) that allows connection to a source of functional fluid.

类似技术:

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公开号 | 公开日 | 专利标题

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同族专利:

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公开号 | 公开日

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US9297214B2|2016-03-29|

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US20130269947A1|2013-10-17|

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EP2627860A2|2013-08-21|

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AU2011316732B2|2015-09-24|

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US20120085544A1|2012-04-12|

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AU2011316732A1|2013-03-28|

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CA2810248A1|2012-04-09|

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CN103154424A|2013-06-12|

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BR112013006446A2|2016-07-26|

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WO2012051149A3|2013-04-04|

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MX342754B|2016-10-12|

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EA201300217A1|2013-09-30|

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US8960302B2|2015-02-24|

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MX2013003789A|2013-08-07|

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EP2627860B1|2020-08-05|

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BR112013007444A2|2018-06-26|

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MX342753B|2016-10-12|

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US20150122503A1|2015-05-07|

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WO2012051149A2|2012-04-19|

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CN103154424B|2016-05-18|

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BR112013007444B1|2020-03-31|

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法律状态:
2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|

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2019-08-06| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|

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2020-02-27| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application according art. 36 industrial patent law|

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2020-06-02| B09A| Decision: intention to grant|

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2020-08-11| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 11/10/2011, OBSERVADAS AS CONDICOES LEGAIS. |

优先权:

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申请号 | 申请日 | 专利标题

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US39244310P| true| 2010-10-12|2010-10-12|

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US61/392,443|2010-10-12|

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US39289910P| true| 2010-10-13|2010-10-13|

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US61/392,899|2010-10-13|

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US201113156258A| true| 2011-06-08|2011-06-08|

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US13/156,258|2011-06-08|

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PCT/US2011/055693|WO2012051148A2|2010-10-12|2011-10-11|Marine subsea assemblies|

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