Key information

Title
OFFSHORE PETROLEUM PRODUCTION
Application number
20221380
Case type
National
Status
11.03.2024 Patent meddelt (B1)
Filed
21.12.2022
Effective date
21.12.2022
Publicly available
11.03.2024
Next annual fee due
31.12.2026
Applicant
Aker Solutions Subsea AS (NO)
Owner
OneSubsea AS (NO)
Inventor
Martin Pedersen (NO)
Agent
ZACCO NORWAY AS (NO)
Granted
11.03.2024
Patent number
347726
Expiry date
21.12.2042

Abstract and drawing

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content.
An offshore petroleum production system (100), the system (100) comprising: a subsea production well assembly (10), a riser (20) anchored at a first end part (20a) thereof to a sea floor (1), a tank assembly (30) fixed to a second end part (20b) of the riser (20), the tank assembly (30) being buoyant and supported vertically by the riser (20), wherein the tank assembly (30) comprises a storage tank (31) fluidly connected to the subsea production well assembly (10) and arranged to receive produced petroleum fluids from the subsea production well assembly (10).

Publications

B1A1
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Documents

 Expand Download files (25)
Date
 Date Doc. No. Process Case number In/Out Journal description To/from
 04.11.2024 07-01 Saksbehandling 20221380(347726) UT PT Varsel om betaling av første årsavgift (3317) (PT20221380) ZACCO NORWAY AS
 30.08.2024 02-01 Endring av søker/innehaver 2024/09023 UT GH Forespørsel OneSubsea AS
 10.06.2024 01-02 Endring av søker/innehaver 2024/09023 INN Firmaattest OneSubsea AS
 10.06.2024 01-01 Endring av søker/innehaver 2024/09023 INN Generell henvendelse OneSubsea AS
 14.03.2024 06-01 Saksbehandling 20221380(347726) UT PT Registreringsbrev nasjonal patent (15) (PT20221380)
22.12.2023 02-01 Endring av søker/innehaver 2023/18565 UT GH Forespørsel ZACCO NORWAY AS
 20.12.2023 02-01 Overdragelse av søknad/rettighet 2023/18507 UT GH Forespørsel ZACCO NORWAY AS
 15.12.2023 05-01 Saksbehandling 20221380 UT Intention to grant ZACCO NORWAY AS
 14.12.2023 01-02 Endring av søker/innehaver 2023/18565 INN NO General Power of Attorney ZACCO NORWAY AS
 14.12.2023 01-01 Endring av søker/innehaver 2023/18565 INN Generell henvendelse ZACCO NORWAY AS
 11.12.2023 01-02 Overdragelse av søknad/rettighet 2023/18507 INN NO General Power of Attorney ZACCO NORWAY AS
 11.12.2023 01-01 Overdragelse av søknad/rettighet 2023/18507 INN Generell henvendelse ZACCO NORWAY AS
 07.12.2023 04-04 Saksbehandling 20221380 INN P452870NO00 Revised Specification (marked) ZACCO NORWAY AS
 07.12.2023 04-03 Saksbehandling 20221380 INN P452870NO00 Revised Specification (clean) ZACCO NORWAY AS
 07.12.2023 04-02 Saksbehandling 20221380 INN P452870NO00 Response to Office Action ZACCO NORWAY AS
 07.12.2023 04-01 Saksbehandling 20221380 INN Korrespondanse (Hovedbrev inn) ZACCO NORWAY AS
 22.06.2023 03-02 Saksbehandling 20221380 UT PT report 09:26:59
22.06.2023 03-01 Saksbehandling 20221380 UT Substantive examination ZACCO NORWAY AS
 21.12.2022 02-01 Saksbehandling 20221380 UT Infobrev til oppfinner ZACCO NORWAY AS
 21.12.2022 01-06 Saksbehandling 20221380 INN Specification ZACCO NORWAY AS
 21.12.2022 01-05 Saksbehandling 20221380 INN NO General Power of Attorney ZACCO NORWAY AS
 21.12.2022 01-04 Saksbehandling 20221380 INN Figures ZACCO NORWAY AS
 21.12.2022 01-03 Saksbehandling 20221380 INN Erklaering ZACCO NORWAY AS
 21.12.2022 01-02 Saksbehandling 20221380 INN Claims and Abstract ZACCO NORWAY AS
 21.12.2022 01-01 Saksbehandling 20221380 INN Søknadsskjema Patent ZACCO NORWAY AS

Description, claims and drawings

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content. Description
OFFSHORE PETROLEUM PRODUCTION SYSTEMThe present disclosure relates to offshore petroleum production systems, and particularly to systems for handling and transport of petroleum products from offshore petroleum fields.BACKGROUNDProduction of petroleum products from offshore fields is well-established and contributes a considerable amount of the petroleum production in many regions of the world. Such fields can be established with a fixed or floating platform at the offshore location, and production equipment on the platform to handle extracted petroleum products via a riser structure. In some cases, subsea wells are established and the wellhead and production equipment are located at the sea floor. In both cases, the produced products are transported further via for example pipelines to shore or a loading facility for transport via tanker ships.The investments required to establish such offshore fields can be considerable, particularly if the petroleum field in question is located remote from shore or from other fields with an established infrastructure for transport of petroleum products. Consequently, even if a discovered petroleum field may contain recoverable hydrocarbons, the investment cost for transport infrastructure may be prohibitive and make the field financially non-viable to develop. Such so-called marginal fields are therefore often left undeveloped.Publications which may be useful to understand the field of technology include WO 2022/129624 A1, which describes storage of fluids underwater; WO 2020/226503 A1, which describes an offshore loading system; US 9316066 B2, which describes a subsea manifold-riser system; and GB 1407497 A, which describes an underwater oil storage apparatus.As the world’s demand for energy continues to rise, there is a need for improved technology relating to handling and transport of petroleum products from offshore fields. The present disclosure has the objective to provide such improvements, or at least to provide useful alternatives to the current state of the art. SUMMARYAccording to the invention, there is provided an offshore petroleum production system, the system comprising: a subsea production well assembly, a riser anchored at a first end part thereof to a sea floor, a tank assembly fixed to a second end part of the riser, the tank assembly being buoyant and supported vertically by the riser, wherein the tank assembly comprises a storage tank fluidly connected to the subsea production well assembly and arranged to receive produced petroleum fluids from the subsea production well assembly. A length of the riser and a height of the tank assembly are such that the tank assembly is fully submerged below a sea surface, and the storage tank is releasable from the riser and operable to be moved by a vessel.The detailed description below and appended claims outline further inventive aspects and embodiments.BRIEF DESCRIPTION OF THE DRAWINGSThe above and other characteristics will become clear from the following description of illustrative, non-restrictive examples, with reference to the attached drawings, in which:Fig.1 is a schematic view of an offshore petroleum production system.Fig.2 is a schematic view of an offshore petroleum production system.Fig.3 is a schematic view of an offshore petroleum production system.Figs 4 and 5 illustrate schematically tank assemblies for use with an offshore petroleum production system.Fig.6 illustrates a tank assembly according to an example.Fig.7 illustrates a tank assembly having an external buoyancy tank.Fig.8 is a schematic view of an offshore petroleum production system. DETAILED DESCRIPTIONFigure 1 illustrates an offshore petroleum production system 100 according to one example. The system 100 comprises a subsea production well assembly 10 arranged at a sea floor 1. The subsea production well assembly 10 comprises a wellbore 11 extending to a subterranean reservoir 12, a wellhead foundation 13 arranged at the sea floor 1, and a valve arrangement 14 (for example a so-called valve tree or Christmas tree) arranged at a wellhead supported by the wellhead foundation 13. The skilled reader will be familiar with this common arrangement of a subsea production well assembly 10. Further components may be part of the subsea production well assembly 10 arrangement and/or connected to it, such as processing equipment, other flow control components, etc. There may also be more than one subsea production well assembly 10 or more than one wellbore 11 and other components associated with the subsea production well assembly 10, for example, a marginal field may comprise 1-3 subsea production well assemblies10, which may also share local sea floor infrastructure.A riser 20 is fixed to the sea floor 1 and extends upwardly from the sea floor 1 in a substantially vertical orientation. The riser 20 is fixed to the sea floor 1 at a first, lower end part 20a of the riser 20. In the illustrated example, the riser 20 is fixed to the sea floor 1 via a foundation 21, in this case shown as a suction anchor foundation. Other types of foundation may equally well be suitable for this purpose. Optionally, the riser 20 may share a common foundation with the subsea production well assembly 10, such as a template structure forming the wellhead foundation 13 and also providing support for the riser 20.A tank assembly 30 is fixed to a second, upper end part 20b of the riser 20. The tank assembly 30 is buoyant, i.e. it has positive buoyancy in water. The length of the riser 20 and the height of the tank assembly 30 are such that the tank assembly 30 is fully submerged, i.e. located below the sea surface 2. The tank assembly 30, by means of its buoyancy, is arranged to maintain or help maintain the riser 20 in a substantially vertical orientation and under tension. The tank assembly 30 thus holds or contributes to hold the riser 20 vertically oriented and prevents the riser 20 from buckling or collapsing. The riser 20 may comprise one or more interconnected pipes, such as steel pipes, and may be made up of a plurality of interconnected riser sections. The riser 20 may have one or more fluid pipes therein, which may or may not be under tension. For example, the riser 20 may comprise a central fluid pipe held in tension by the buoyancy force from the tank assembly 30, or it may comprise a fluid pipe and one or more auxiliary tension member (e.g. auxiliary pipe(s) and/or steel wire(s)) which relieve the pipe such that the central pipe is under less or no tension.In some examples, the riser 20 may itself comprise buoyancy members arranged thereon, such as to maintain a vertical orientation also without a tension force provided by the tank assembly 30.The tank assembly 30 further comprises a storage tank 31 fluidly connected to the subsea production well assembly 10 and arranged to receive produced petroleum fluids from the subsea production well assembly 10. The storage tank 31 provides a temporary storage for petroleum fluids. The storage tank 31 may, for example, be a container structure arranged inside or otherwise in conjunction with the tank assembly 30. The tank assembly 30 and the storage tank 31 may optionally be formed integrally, so that the tank assembly 30 is or makes up the storage tank 31. The fluid connection between the subsea production well assembly 10 and the storage tank 31 may preferably be via one or more fluid pipes in (or part of) the riser 20 or, optionally, one or more fluid pipes fixed to the riser 20. Illustrated in Fig.1, connector pipes (for example so-called jumpers) 15,16 may be arranged to convey produced petroleum fluids from the subsea production well assembly 10 to the riser 20 and to the storage tank 31. Flow control and processing equipment, which may include e.g. valves, throttles, pumps, separators and/or fluid conditioning equipment, may be arranged at the subsea production well assembly 10, in or at the valve arrangement 14, and/or between the subsea production well assembly 10 and the storage tank 31. In Fig.1, equipment 17 between the subsea production well assembly 10 and the storage tank 31 is illustrated. A pump package may be arranged as part of the flow control and processing equipment, between the subsea production well assembly 10 and the connection to the riser 20. In some examples, the pressure in the reservoir 12 may be sufficiently high that no pump package is required, and that fluid flow to the storage tank 31 is driven by reservoir pressure. In the illustrated example, an offloading arrangement 40 comprises an offloading pipe 41 configured to be retrieved by a tanker vessel 42 (such as a shuttle tanker) and for moving petroleum fluids from the storage tank 31 to the tanker vessel 42. In the illustrated example, the offloading pipe 41 is retrievable by the vessel 42 via an offloading buoy 43, and the offloading pipe 41 is arranged in a catenary between the tank assembly 30 and the offloading buoy 43.In an alternative configuration, the tanker vessel 42 may have an offloading pipe 41 which is lowered into the water and down to the tank assembly 30 for connection e.g. at a top part of the tank assembly 30. This configuration is illustrated schematically in Fig.3. The offloading pipe 41 may, for example, comprise an end connector which is landed and locked in a corresponding connector receiver in or at the tank assembly 30. A suitable pump arrangement, for example arranged in the offloading pipe 41 or in the tank assembly 30, may be provided to move the petroleum fluids to the tanker vessel 42.Illustrated in Fig.2, in one example the storage tank 31 may be releasable from the riser 20. In this example, the storage tank 31 may be fluidly connected to the riser 20 and receive petroleum fluids from the subsea production well assembly 10 and subsequently be released from the riser 20 for transporting the petroleum fluids away while contained in the storage tank 31. The storage tank 31 may, for example, be configured to be towed by a vessel 42’, which in this case does not have to be a tanker vessel but can be, for example, an offshore service vessel. The storage tank 31 may, for example, be towed to shore or a quayside for emptying or towed to another offshore location (such as another petroleum field installation) having suitable infrastructure for handling and further transport of the petroleum fluids. The storage tank 31 can then be emptied and returned for re-connection to the riser 20. In the illustrated example, the storage tank 31 is arranged in a first tank assembly part 30a which can be released from the second tank assembly part 30b.Alternatively, the storage tank 31 may make up or be part of an own structure which is disconnectable from the tank assembly 30. Yet alternatively, the entire tank assembly 30 (see Fig.1) may be disconnectable from the riser 20 for this purpose. In the first case, as illustrated in Fig.2, the second tank assembly part 30b may be designed to have sufficient buoyancy to maintain the required tension in the riser 20 and/or to have a required self-buoyancy also with the first part 30a disconnected. In the latter case, one may provide a second tank assembly 30 which is fixed to the riser 20 as or before a first tank assembly is disconnected. In this manner, save possibly for the short switching process, one tank assembly 30 is always connected to the riser 20, thereby also permitting substantially continuous loading via the riser 20. For example, one may design the system 100 with two tank assemblies 30 having a capacity such that the filling of one tank assembly approximately matches the time required to tow away and empty the other tank assembly.In other examples, illustrated in Fig.3, the riser 20 may have more than one storage tank 31a,b attached to it, for example two, three or four storage tanks 31a,b, and the storage tanks 31a,b can be disconnected at different times, such that there is always one storage tank 31a,b attached to the riser 20 for receiving petroleum fluids. The storage tanks 31a,b may be arranged as removably connectable to a tank assembly 30, for example where a tank assembly part 30b has connection arrangement to allow each of the storage tanks 31a,b to be connected thereto to disconnected therefrom. Alternatively, the second tank assembly part 30b may be replaced by a feature on or part of the riser 20 which permits releasable connection of the storage tanks 31a,b individually.Fluid connection between the one or more releasable storage tank(s) 31a,b and the riser 20 may be provided by a connector arranged for example in a landing feature at the riser 20 or at the tank assembly part 30b. This may, for example, be a vertically arranged connector arrangement where a connector part on the respective storage tank 31a,b lands vertically into a corresponding connector part in the tank assembly part 30b and a fluid connection is subsequently made up. Alternatively, or additionally, the fluid connection may be provided by e.g. a flexible connection 37, illustrated schematically in Fig.3, which may be connected externally to the storage tank(s) 31a,b. The flexible connection can, for example, be made up with the assistance of a remotely operated underwater vehicle (ROV), a robotic arm, or by other suitable means.Figs 4 and 5 illustrate an example of an arrangement of multiple storage tanks onto one tank assembly part 30b which is fixed to the riser 20. In Fig.4, four storage tanks 31a-d are shown, individually arranged as indicated in the top view of the tank assembly 30 shown in the upper part of the figure. In Fig.5, three storage tanks 31a-c are used. Each of the storage tanks 31a-c may be arranged as part of a tank assembly part 30a, as described in relation to Fig.2.The riser 20, tank assembly 30 (e.g., the tank assembly part 30b) and/or the storage tank(s) 31,31a-d may contain necessary valves and other flow control components to control fluid flow to the individual storage tank(s) 31a-d.Fig.6 illustrates an example of a tank assembly 30 as illustrated in Fig.1. The tank assembly 30 in this example comprises a storage tank 31 in the form of a compartment 35 in the tank assembly 30. In configurations where the storage tank 31 is releasable, the storage tank 31 may be arranged in a tank assembly part 30a which is releasable from tank assembly part 30b, as described above. The configuration in Fig.6 may also be used for each of a plurality of storage tanks 31ad, for example in configurations as shown in Figs 4 and 5.The compartment 35 is here illustrated partly filled with petroleum fluids 32.The tank assembly 30 in this example further comprises a gas compartment 34 for buoyancy. The gas compartment 34 may contain air or another suitable gas or gas mixture. In some examples, the gas compartment 34 may be a bladder or equivalent container. The tank assembly 30 may have arrangements for varying the buoyancy, for example the tank assembly 30 may have a pump arrangement operable to pump sea water into or out of the gas compartment 34 so as to change the volume available for the gas. Fig.6 illustrates water 33 having been pumped into the gas compartment 34, whereby the gas contained therein will be compressed, and the buoyancy of the tank assembly 30 is reduced. In this manner, by pumping water into or out of the gas compartment 34, the buoyancy of the tank assembly 30 can be regulated, for example in order to maintain a close to constant buoyancy force on the riser 20 as the storage compartment 35 is gradually filled with petroleum fluids. An extra buoyancy tank 39, illustrated schematically in Fig.7, may be fixed to the tank assembly 30 as required, for example externally to the tank assembly 30 and/or separately but mechanically connected to the tank assembly 30 e.g. via wire ropes or other means. In any of the examples and embodiments described herein, the buoyancy of the tank assembly 30 or individual storage tank(s) 31,31a-d may be variable such that the buoyancy is reduced when installing the tank assembly 30 and/or the storage tank(s) 31,31a-d.Illustrated in Fig.2, but applicable to any of the examples or embodiments described or claimed herein, the system 100 may comprise one or more flexible joints 38a,b connecting the riser 20 to the foundation 21 and/or connecting the riser 20 to the storage tank(s) 31,31a-d. A flexible joint 38a may, for example, be arranged at the lower end part 20a of the riser 20 at the interface towards the foundation 21 and/or at the interface between the upper end part 20b of the riser 20 and the tank assembly part 30b. This can assist in limiting bending loads applied to or from the riser 20 during operation.Fig.8 schematically illustrates an example exchange operation for a storage tank 31a-d in a tank assembly 30 comprising a plurality of storage tanks 31a-d. A full storage tank 31a is released from the riser 20. This can be done with the assistance of an ROV 36 which is controlled from the vessel 42’, for example as illustrated in this example by operating the ROV 36 to release the storage tank 31a from the tank assembly part 30b. A replacement, empty storage tank 31d is provided and installed in the place of the removed storage tank 31a. This can similarly be done with the assistance of the ROV 36, for example to make up structural and/or fluid connections to the replacement storage tank 31d.The storage tanks 31a-d may be towed by the vessel 42’ between their installation site and another site, such as a quayside or offshore unloading facility. This reduces the requirements for the vessel 42’.By temporary storing petroleum fluids in a storage tank 31 being part of a tank assembly 30 as described in the examples herein, the need for sea floor structures for storage can be eliminated or reduced. Such conventional sea floor storage tanks may need to be ballasted down and/or anchored to the sea floor to avoid floatation. Access to such a sea floor storage may also be challenging, particularly in deep waters. The riser 20, tank assembly 30 and other components may be re-usable. For example when an existing marginal field is depleted, some or all of the components in the system 100 can be moved to a new field and continue to be used in the same manner as described above.The invention is not limited by the embodiments described above; reference should be had to the appended claims.
Claims
CLAIMS1. An offshore petroleum production system (100), the system (100) comprising:a subsea production well assembly (10),a riser (20) anchored at a first end part (20a) thereof to a sea floor (1), a tank assembly (30),the tank assembly (30) being buoyant and supported vertically by the riser (20), and a length of the riser (20) and a height of the tank assembly (30) being such that the tank assembly (30) is fully submerged below a sea surface (2),wherein the tank assembly (30) comprises a storage tank (31,31a-d) fluidly connected to the subsea production well assembly (10) and arranged to receive produced petroleum fluids from the subsea production well assembly (10), characterised in thatthe tank assembly (30) is fixed to a second end part (20b) of the riser (20) and thatthe storage tank (31,31a-d) is releasable from the riser (20) and operable to be moved by a vessel (42’).2. The offshore petroleum production system (100) of claim 1, further comprising an offloading arrangement (40), wherein the offloading arrangement (40) comprises an offloading pipe (41) configured to be operatively engaged by a tanker vessel (42) for moving petroleum fluids from the storage tank (31,31a-d) to the tanker vessel (42) via the offloading pipe (41).3. The offshore petroleum production system (100) of claim 1, wherein the tank assembly (30) is configured to receive an offloading pipe (41) for moving petroleum fluids from the storage tank (31,31a-d) to a tanker vessel (42).4. The offshore petroleum production system (100) of any preceding claim, comprising a plurality of storage tanks (31,31a-d).5. The offshore petroleum production system (100) of claim 4, wherein each of the plurality of storage tanks (31,31a-d) is releasable from the riser (20) and operable to be moved by the vessel (42’).6. The offshore petroleum production system (100) of any preceding claim, wherein the tank assembly (30) comprises a variable buoyancy arrangement.7. The offshore petroleum production system (100) of claim 5, wherein at least one or each of the plurality of releasable storage tanks (31,31a-d) comprises a variable buoyancy arrangement.8. The offshore petroleum production system (100) of claim 6 or 7, wherein the variable buoyancy arrangement comprises a variable-volume gas compartment (34).KRAV1. Et offshore petroleumsproduksjonssystem (100), hvor systemet (100) omfatter:en undervanns produksjonsbrønnsammenstilling (10), et stigerør (20) forankret ved en første endedel (20a) derav til en sjøbunn (1),en tanksammenstilling (30),hvor tanksammenstillingen har positiv oppdrift og er støttet vertikalt av stigerøret (20), og en lengde av stigerøret (20) og en høyde av tanksammenstillingen (30) er slik at tanksammenstillingen (30) er fullstendig neddykket under en havoverflate (2),hvor tanksammenstillingen (30) omfatter en lagringstank (31,31a-d) som er fluidforbundet til produksjonsbrønnsammenstillingen (10) og innrettet til å motta produserte petroleumsfluider fra produksjonsbrønnsammenstillingen (10), karakterisert ved at tanksammenstillingen (30) er festet til en andre endedel (20b) av stigerøret (20), og atlagringstanken (31,31a-d) er løsbar fra stigerøret (20) og kan beveges av et fartøy (42’).2. Offshore petroleumsproduksjonssystemet (100) ifølge krav 1, videre omfattende et lossearrangement (40), hvori lossearrangementet (40) omfatter et losserør (41) konfigurert til å bli operativt innkoplet av et tankskip (42) for flytting av petroleumsfluider fra lagringstanken (31,31a-d) til tankskipet (42) via losserøret (41).3. Offshore petroleumsproduksjonssystemet (100) ifølge krav 1, hvor tanksammenstillingen (30) er konfigurert til å motta et losserør (41) for flytting av petroleumsfluider fra lagringstanken (31,31a-d) et tankskip (42).4. Offshore petroleumsproduksjonssystemet (100) ifølge hvilket som helst foregående krav, omfattende et flertall lagringstanker (31,31a-d).5. Offshore petroleumsproduksjonssystemet (100) ifølge krav 4, hvor hver av flertallet lagringstanker (31,31a-d) er løsbar fra stigerøret (20) og kan beveges av fartøyet (42’).6. Offshore petroleumsproduksjonssystemet (100) ifølge hvilket som helst foregående krav, hvor tanksammenstillingen (30) omfatter et variabelt oppdriftssystem.7. Offshore petroleumsproduksjonssystemet (100) ifølge krav 5, hvori minst én eller hver av flertallet løsbare lagringstanker (31,31a-d) omfatter et variabelt oppdriftssystem.8. Offshore petroleumsproduksjonssystemet (100) ifølge krav 6 eller 7, hvori det variable oppdriftssystemet omfatter et gassrom (34) med variabelt volum.
Drawings

Priority

No priority

Patent classes

IPC classesE21B 17/01B63B 22/24E21B 43/01B63B 35/44CPC classesE21B 17/012B63B 22/24E21B 43/01B63B 35/44

Citations

WO 2022/129624 A1 (A1)WO 2020/226503 A1 (A1)US 9316066 B2 (B2)GB 1407497 A (A)

Applicants, owners and inventors

Owners
OneSubsea AS
Strandveien 4 1366 LYSAKER NO (BÆRUM Municipality, Akershus county)Org. number: 929765001Inventors
Martin Pedersen
Lilloe-Olsens vei 17 B 0489 OSLO NO (OSLO Municipality, Oslo county)

Agent

ZACCO NORWAY AS
ZACCO NORWAY AS

Org. number: 982702887

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Open in The Brønnøysund Register Centre
Postboks 488 0213 OSLO NO (OSLO Municipality, Oslo county)
Org. number: 982702887
Reference: P452870NO00

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